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185-109
Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 185 -1 09 2Z Ͳ16 Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, June 14, 2021 2:17 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C; Well Integrity Specialist CPF2 Subject: CPAI 2Z-16 (PTD #185-109) report of increasing IA pressure. Attachments: 2Z-16 90 Day TIO 14 June 21.pdf; 2Z-16.pdf Chris- Kuparuk Injector 2Z-16 (PTD #185-109) was identified during the review of the Waivered Injection Well Report as having an IA pressure which has slowly started increasing. The well has been previously classified as a "Troubled" well and has been shut in and secured since Sept of 2006. CPAI intends to conduct a series of initial diagnostic tests to investigate the increase in IA pressure. Depending on the results of the tests the proper notifications will be submitted at that time. Please let me know if you have any questions or disagree with the plans. Attached is a 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM �on�aPFdnlps ~ `--` . . ConocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~v~~b9 ~ ~~ ~ ~ ~ Enclosed please find a spreadsheef with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 20th and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 15~' and 31 St + November 1 St and 2na 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ~mcerely, ~ p~ Perry Klei-n v ~ ~,~~~~~~~~~~ °~~CJ ir' ~. ~~ f.CO~ ~~~~~~r ~ ~ ~~ ~"~~a ~~~~~ ~~tnmission ~l31C~ ai ~~~ w~~:~;t"A~~~~'^~~ ? ~'~I ~'4 ,~ 4~ ~-~' ~0~ ~ ConocoPhillips Well Integrity Projects Supervisor • ! ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C_ 2D_ 2Z & 3K Pad Well Name API # PTD # Initial top of cement Vol, of cement um ed Final top of cement Cementtop off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10l15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10131/2009 2C-O6 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' S.5 22" 10/13/2009 4.67 10l31l2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/1/2009 2D-11 500292113A0000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11/2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11l1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 M RA.NDUM State of Alaska • To: Jim Regg f 7 P.I. Supervisor ~~~ ~ ` Z~~~~' t FROM: John Crisp Petroleum Inspector Alaska Oil and Gas Conservation Commi DATE: Thursday, September 27, 200 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-16 KUPARIJK RIV UNIT 2Z-Z 6 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ' ~-- Comm Nell Name: KUPARUK RN UNIT 2Z-16 Insp RTum• mitJCr070925133932 Rel Insp Num: API Well Number: 50-029-21363-00-00 Permit Number: 185-io9-o Inspector Name: John Crisp Inspection Date: 9%'2512007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2Z-I6 ;Type Inj. i N '; TVD ~ 5673 ~~ IA ~! 6so zsoo ! ~ zaao ~ zaoo P.T. ' Ias~oso ~TypeTest sPT i Test psi j zsoo -'i OA ~ azo - iazo ~ azo ~ azo Interval °T~R P/F t. i~' Tubing I aso 6so 0o i bbo ! ~~ ~ ~ ~~~ . NOteS' ~ Pressure test after cementing packer Leak. ~1"~' Z'~J.vL~~- t~.~'r` ~,Zi,^<? S ~'U~i - t'.~ -~~w~'=~ Z-~l~Pt ,~S ' 'C~S~~- ~~[~';(.l.C:~i~t:.~ ~~ (~f?c1i~~S 1 L ~ ~'t'C. t saCc~' f'(J ' k Z'd~ C_G%;'~~!`"\i.[; t, L 2Lc.~t,Y'\ / ~Fi y~'-i /ati j~f{~ IL{'f" , iJ Thursday, September 27, 2007 Page 1 of i MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Comm TO: ~~ ~'r DATE: Thursday, September 27, 2007 Jim Regg ~ ~~ ~ 1 ~`~~~t= P.I. Supervisor ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-16 FROM: John C17Sp KUPARUK RIV UNIT 2Z-16 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv _~.~- NON-CONFIDENTIAL Comm Well Name: KUPARUx RIV UNIT 2z-16 API Well Number: 50-029-21363-00-00 Inspector Name: John Crisp Insp Num: mitJCr070925134354 Permit Number: 1 RS-109-0 Inspection Date• 9/25/2007 Rel Insp Num: Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well ~ 2Z-76 Type Ind. ~ N I, Tj7D 5673 ~" ~ IA I 2400 ~ 2500 ~ 2480 ~ 2470 ~ ~ _I P.T. '~ ]851090 ~T~'peTeSt ~ SPT ~ TeSt pSl ~ - Ti 2500 '~ QA ~ 420 ~ 430 1 J ~ 430 J 430 ~~ I } Interval oTr->ER p~F P ~ Tubing i bbo i 660 ~ 660 66o NOteS: Pressure test lA after packer lead cemented. 2 bbl's pumped for test . ~ - -- I ~~i:~ ~C~'~~Cr- i~ ~ ii~d>~~ iVU y ~ ~ LUU~ Thursday, September 27, 2007 Page 1 of 1 . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 02,200710:50 AM To: 'Eller, J Gary' Cc: Salas, Jose Ricardo; NSK Problem Well Supv; CPF2 Prod Engrs Subject: RE: 2Z-16 (185-109) Thanks Gary. I will add this message to the file. It was unclear from reading the operations summary that you indeed had some success. I guess my interpretations are biased toward the "dark side" when I see fish and other equipment still in the hole when the operations are halted. I have no further questions. Tom Maunder, PE AOGCC ~----_._--~.~_.---".~~-'.--------,-----" From: Eller, J Gary [mailto:J,Gary,Eller@conocophillips.com] Sent: Thursday, August 02,200710:23 AM To: Maunder, Thomas E (DOA) Cc: Salas, Jose Ricardo; NSK Problem Well Supv; CPF2 Prod Engrs Subject: RE: 2Z-16 (185-109) 5~;ANNED AUG 0 7 2007 Tom - We conducted a successful MIT-IA of 2Z-16 on 6/3/07. We'll now monitor the IA for the next several weeks to see if we have adequately addressed the influx of gas that was pressuring up the IA. As of today we show no trend of pressure increase on the lA, so it looks good so far. We did run a $CMT log which showed little or no cement placed above the packer at 7357' MD, but despite that it looks like we have'achieved'our'þnmary objective of securing the well. Long term, I'm not sure what the future holds for 2Z-16. We still have a fish in the tubing (i.e. mill and motor from cement cleanout on 6/21/07) which we have thus far been unable to recover, as well as a 3.5" cement retainer at 7480' MD. We ultimately would like to resume water injection into the A Sand, but right now the water supply line to 2Z pad is out of commission. Summary: I expect that 2Z-16 will remain shut-in for quite a while. Please call if you'd like to discuss further. -Gary -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska,gov] Sent: Wednesday, August 01,200711:09 AM To: Eller, J Gary Subject: 2Z-16 (185-109) Hi Gary, I am reviewing the 404 you sent in for the squeeze and cleanout work on this well, Where do you plan to go from here (or there)? Tom 8/2/2007 · · k STATE OF ALASKA ~ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION It.¡ REPORT OF SUNDRY WELL OPERATIONS JUL 1 9 Z007 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 A¡a~~~il & GI;JCOf\s. Ci}mmissip, Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time ExtensionA~Oïa\}e Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 185-109/ " 3. Address: Stratigraphic 0 Service 0 " 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21363-00 '" 7. KB Elevati?n (ft): 9. Well Name and Number: RKB 109' 2Z-16 ,- 8. Property Designation: 10. Field/Pool(s): ADL 25646, ALK 2577 Kuparuk River Field / Kuparuk Oil Pool .- 11. Present Well Condition Summary: Total Depth measured 8150' , feet true vertical 6248' , feet Plugs (measured) 7715', retainer @ 7662' Effective Depth measured 7875' feet Junk (measured) patch @ 7676', 7466' mill & motor true vertical 6053' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 103' 16" 103' 103' SUR. CASING 3972' 9-5/8" 4081' 3323' PROD. CASING 7993' 7" 8102' 6214' Perforation depth: Measured depth: 7656'-7661',7800'-7806', 7818'-7844', 7866'-78~ED AUG Q, '7 2007 true vertical depth: 5896'-5899',6000'-6004',6012'-6031',6047'-6064' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7722' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' ; HES Fasdrill sqz pkr; BAKER 'FB-1' pkr= 7357'; 7480'; 7699' Baker 'FVL' SSSV @ 1807' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7514'-7614' Treatment descriptions including volumes used and final pressure: 34 bbls 15.8 Class G 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation SI -- Subsequent to operation SI '" -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 0 0 '" Development Service Daily Report of Well Operations _X 16. Well Status after work: OilD GasD WAG 0 GINJD WINJ 0 ' WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 30(k252 \. Contact Gary Eller @ 263-4172 Wells Group Engineer \~~~ Printed Name Gary Eller Title -1 ~jiJ2 Signature Phone Date '( l >1 Prenl'lred bv Sh on All rake 263-4612 n Form 10-404 Revised 04/2006 0 R , GIN A L RBDMS 8Ft AUG 0 7 20D1 ~ 7·1-7.01 Submit Original Only ~ :#/~7 . 2Z-16 Well Events Summary . DATE Summary 8/31/06 ATTEMPT TO PULL SLIP STOP (MOVED IT UP HOLE -600'). GET LIB IMPRESSION OF CLEAR "G" FISH NECK. IN PROGRESS. 9/1/06 PULL 3 1/2" 0&0 SLIP STOP FROM 7006' SLM. RIG UP 60 TON CRANE AND ATTEMPT TO PULL TOP SECTION OF PATCH ASSEMBLY. PULL SETTING SLEEVE. 3" RB WON'T FALL PAST STATION #1 AT 7304' RKB. DAMAGE SKIRT ATTEMPTING TO WORK BY, 1.5" RM LATCH IS BENT OVER INTO TUBING. ATTEMPT TO PULL 1.5" DGLV/RM, DAMAGE 2" SM TRYING. 2.7" 00 KICK OVER TOOL DRIFTS THROUGH MANDREL SEVERAL TIMES. 9/2/06 RUN LlBS AND DETERMINE OBSTRUCTION IN TUBING IS GLM DEFLECTER BREAKING FREE FROM TUBING WALL AT 7303' RKB. TROUBLESHOOT OBSTRUCTION AND GET A 2.8" TAPERED CENTRALIZER THROUGH. RUN LIB AND CONFIRM DEFLECTER HAS BEEN PUSHED BACK AGAINST TUBING WALL SLIGHTLY. 9/3/06 SWAGE DEFLECTOR AT 7303' RKB BACK AGAINST TUBING WALL AGAIN AFTER SEVERAL FAILED ATTEMPTS TO PASS THROUGH.. GET THROUGH GLM AT 7303' W/ BOW SPRING CENTRALIZER ON TOP OF PULLING TOOL. RIG UP 60 TON CRANE AND 2 SECTIONS OF 8' RISER. PULL TOP SECTION OF PATCH ASSY. SHEAR GR TRYING TO PULL BOTTOM SECTION. DEFLECTOR OF GLM AT 7303' RKB HAS STARTED TO DETACH FROM TUBING WALL. 9/17/06 PULLED LOWER STRADDLE PACKER ASSY. (32.14' OAL) FROM 7715' RKB. JOB IN PROGRESS. 9/18/06 SET 2.25" CS-2 BLANKING PLUG W/1 3/4" FN ON PRONG AND BODY @ 7715' RKB, ONLY ABLE TO GET 2.285" MAX 10 THROUGH PERMANENT PATCH, DUMP 5' OF CALCIUM CORBANATE 7710' RKB 9/22/06 ATTEMPT TUBING PUNCH. FOUND HES PERMANENT PATCH HAD FALLEN APPROX SIX FEET. PATCH NOW COVERS DEEPEST INJECTION MANDREL AND 10' PUP BELOW. MADE 2-AXIS CALIPER RUN TO CONFIRM PATCH/JEWELRY. 9/23/06 PREP WELL FOR C-SAND P&A. PUNCH 3.5" TUBING PUP JOINT BELOW THE INJECTION MANDREL AT 7679' TO ALLOW FOR CIRCULATION TO STRADDLE. PUNCH INTERVAL 7691'-7694'FIRED 2.00" HSD GUN LOADED 3 FT AT 2 SPF, 180 DEG PHASED. BIG HOLE "27C" CHARGES USED TO PUNCH THRU HES PATCH AND 3.5" TUBING. SET 3.5" HES EZ-SVB CEMENT RETAINER IN PUP ABOVE SAME MANDREL AT 7661.6' MD ELEMENT. 10/11/06 Used several methods in an attempt to achieve circulation through HES cement retainer. Pump while stinging into retainer at 7,663.2' CTMD. Raise WHP to 3,000 PSI while attempting to sting in, surging, IA bleed off, violent under-balancing of HES stinger assembly. 10/13/06 PREPARE WELL FOR 'C' SAND STRADDLE CEMENT SQUEEZE. PUNCHED TUBING @7490-7492' IN FULL JOINT BELOW MIDDLE INJECTION MANDREL. PUMPED DOWN TUBING TO 'C' SAND AT 2 BPM 1600 PSI. BLED OFF IA TO ZERO. DISPLACED TUBING TO DIESEL - TUBING PRESSURE 650 PSI. BLED OA TO 300 PSI. BULLHEAD 86 BBL DIESEL INTO IA. ESTABLISH IA INJECTION RATE AT 2000 PSI, 0.6 BPM. SET HES FASDRILL SQUEEZE PACKER WITH MID ELEMENT AT 7480' ELMO (10' BELOW BOTTOM OF MIDDLE INJECTION MANDREL). WELL LEFT SHUT IN. . 2Z-16 Well Events Summary . 5/28/07 Performed an C-sand squeeze /IA plug. Injected 34 BBLS of 15.8# Class G cement w/gas block. 12.5 BBLS of cement between jewelry - 16 BBLS behind pipe in C-sand formation - 4 BBLS above packer into IA - 2.5 BBLS above HES cement retainer in 3.5" production tubing. Tubing and IA loaded with diesel for freeze protect to top of cement. 6/3/07 MITIA-PASSED 6/12/07 GAUGED TBG TO 2.79" TO 5910' SLM. AGAIN TAG OBSTRUCTION @ 5915' SLM WITH 2.25" GAUGE RING, PROBABLE CEMENT STRINGERS. TRACES OF CEMENT IN TOOL STRING CONNECTIONS & GAUGE RINGS. 6/20/07 Removed cement stringer's in tubing from 6,051' to 6,114' CTMD before BHA became plugged off with rocks found on inspection at surface. Purged coil at surface with clean sea water at max rate. Re-installed new BHA for re-start in the AM. 6/21/07 Milled up 15.8# LARC cement from 6,136' CTMD to 7,440' CTMD using 2.75" three bladed junk mill. Well freeze protected with diesel to 7,440' CTMD - 7,460' RKB. Left Weatherford PDM W/2.75 mill in hole @ 7,420' RKB. Fish length left in hole = 12.68' Fish neck is Weatherford 1.91" catch. 6/23/07 ATTEMPTED TO FISH CTB. MILL AND ENCOUNTERED CEMENT BUILD UP ON TBG. WALL. RAN GAUGE RINGS WORKING UP TO 2.71 DOWN TO 7387' SLM. RAN 2.5 PUMP BAILER AND RECOVERING CEMENT CHUNKS DOWN TO 7390' SLM ( CTB. FISH @ 7420' RKB). 6/24/07 ATTEMPT TO BAIL DOWN TO PULL CTB. FISH @ 7420' RKB. UNABLE TO BAIL OR BREAK THROUGH WHAT APPEARS TO BE CEMENT BRIDGE IN TBG. @ 7390' SLM. 6/30/07 MADE FCO RUN to 7400' CTMD USING BIO AND SLICK SEAWATER. SET DOWN AT 7412' CTMD ABLE TO WASH DOWN TO 7455' CTMD, LOOKS LIKE MAYBE WE PUSHED FISH DOWN AN ADDITIONAL +/- 20', MADE FISHING ATTEMPT BUT WERE UNSUCCESSFUL. 7/15/07 LOGGED SLIM CEMENT MAPPING TOOL. PRESSURED UP TUBING WITH LITTLE RED TO 1000# AND LOGGED FROM 7450' TO SURFACE.OBSERVED VERY LITTLE CEMENT ABOVE PACKER AT 7352'. . . KRU 2Z-16 ConocoPhillips Alaska, ¡Inc. API: 500292136300 Well Tvoe: INJ Anale ía) TS: 41 deo @7514 TUBING SSSV Type: LOCKED OUT Orig 6/10/1005 Angle @ TD: 45 deg @815O (0-7722. Camoletion: 00:3.500, 10:2.867) Annular Fluid: Last W/O: Rev Reason: CMT SQUEEZE, TAG OBSTRUCTION Reference Loa: Ref Loa Date: Last Uodate: 6/17/2007 Last Taa: 7875 TD: 8150ftKB Last iBiir 4/6/20(» Max Hole Anale: 48d~61oo DescriDtion Size Ton Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 103 103 62.50 H-40 SUR. CASING 9.625 0 4081 3323 36.00 J-55 PROD. CASING 7.000 0 8102 6214 26.00 J-55 rn I Size I Too I Bottom I TVD I Wt I C::'RtlA ThrARtI 1 3.500 1 0 I 7722 I 5943 I 9.30 1 J-55 I 8RD EUE p= Interval TVD Zone Status Ft ISPF Dale Tvoe Comment 7514 - 7614 5791 - 5865 4,C-3,C-2,C C 100 0 5/28/2007 Saz 7656 - 7661 5896 - 5899 UNITB 5 12 7/10/1005 IPERF 120 deg. phase; 5.5" Hyper Jet II 7800 - 7806 6000 - 6004 A-5 6 4 7/10/1005 IPERF 90 den. nh;4" HVDer Jet II 7818-7844 6012 - 6031 A-4 26 4 7/10/1005 IPERF 90 dea. oh;4" HVDer Jet II 7866 - 7890 6047 - 6064 A-3 24 4 7/10/1005 IPERF 90 _HVDer Jet II Interval I Date I Tvoe I Comment 7514 - 7614 5/28/2007 CEMENT I CEMENT SQUEEZE 34 BBLS 15.8 CLASS G SQUEEZE J4ii$::I¡Ii' ----~"- , 51 MD TVD Man Mfr Man Type VMfr V Type VOD latch Port TRO Date Run VIv Cmnt 1 7304 5632 Merla I TMPD DMY 1.5 I RM T 0.000 1 0 5/9/2000 * " L ~% 51 MD TVD Man Mfr Man Type V Type latch Port ,Run Vlv Cmnt 2 7394 5701 Merla TMPD DMY 1.5 RM 0.000 0 12/7/1997 Wloka 3 7465 5754 Merla TMPD DMY 1.5 RM 0.000 0 12/7/1997 WIDka 4 7679 5912 Merla TMPD DMY 1.5 RM 0.000 0 4/6/20(» DeDth TVD Tvoe Descriotion ID ..:. 1807 1709 SSSV Baker'FYL' (LOCKED OUT 4/4/2004) 2.812 F =t 7343 5662 PBR Baker 3.000 7357 5673 PKR Baker 'FHL' 3.000 7480 5766 PACKER HES FASDRILL SQUEEZE PACKER set 10/13/2006 0.000 ~ '----- 7490 5773 TBG MEDIUM TUBING PUNCHES 7490'-7492', TOTAL OF 9 PUNCHES 0.000 ~ ~ Punches 10/13/2006 7662 5900 RETAINER 3.5" HES EZ-SUB CEMENT RETAINER set 9/23/2006 0.000 7676 5910 PATCH HES PERMANENT PATCH set OVER GLM #4 FELL 6' AFTER BEING 2.360 SET. LEAK FOUND ía) 7675' AT TOP OF PATCH 4/16/2004 7691 5921 TBG TBG PUNCHES THRU PERMANENT PATCH, 2 SPF, 180 DEGREE 0.000 PATCH Punches 9/23/2006 (7676-7692, 7699 5927 PKR Baker 'FB-1' 3.000 00:3.500) 7715 5938 NIP Cameo 'D' Nioole NO GO 2.750 7715 5938 PLUG 2.25" CS-2 PLUG set 9/18/2006 0.000 7715 5938 NIP RED NIPPLE REDUCER ('D' PROFILE) set 4/15/2004 2.250 7721 5943 SOS Cameo 2.992 7722 5943 TTL 2.992 Date I Note 2/20/199~ NOTE: LEAK Detect shows UDDer PKR Leak ía) 7355' RKB. 9/18/20061 NOTE: 5' CaC03 DUMPED@ 7710' M - f----- - f-- - f-- - f-- - f-- - f-- 07/23/07 Scblumbepgel' i"'/"'I·'"'''' H ,~ 1 .'7Z'''''l1 II '1; != NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dUL 2 5 Z007 iì!ñ.skaOíl8· Cons. Gommission'rANNED JUL 2 7 2001 ¡~nch{)mge 5 'wi Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: ù:cc...- 106 - (O~ Field: Kuparuk Well Log Description Color CD BL Job# Date \1/ 2M-20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20. 11665456 INJECTION PROFILE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1 R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 LDL 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 USIT 07/16/07 1 2Z-16 11665458 SCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L-07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Eller Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 \q;5' ~ \ DO¡ "(9 e;µJ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2Z-))(' Sundry Number: 306-252 Dear Mr. Eller: ì./':'~ t, . ,,) 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this..ztday of July, 2006 Enc!. e Conoc6Phillips e Gary Eller Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 July 20, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2Z-16 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 2Z-16. The objectives of this workover are to secure the well sufficiently to eliminate gas from entering the IA from the C Sand, to achieve an adequate squeeze of the C Sand such that injection can resume into the A Sand, . and to leave the well set up for a future CTD sidetrack in the A Sand. If you have any questions regarding this matter, please contact me at 263-4172. JGE/skad STATEb:~LA:!~('. A,~~ RJ:~~I~~~ ALASKA Oil AND GAS CONSERVATION COMMISSION 6 APPLICATION FOR SUNDRY APPROV AL\laska Oil & Gas Cons. Commission 20 AAC 25.280 Anchora e o Time Extension 0 Re-enter Suspended Well 0 e 1. Type of Request: o o o o 0· o Perforate 0 o Abandon Operational Shutdown o 0- o Stimulate Suspend Alter casing Repair well Plug Perforations Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Pull Tubing Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 Waiver Other 0 5. Permit to Drill Number: 185-109 - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21363-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes 0 No 0· 2Z-16 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25646: ALK 2577 RKB 109' Kuparuk River Field 1 Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8150' - 6248' 7875' patch @ 7650' Casing Length Size Burst Collapse CONDUCTOR SUR. CASING PROD. CASING MD TVD 103' 103' 4081' 3323' 8102' 6214' 103' 3972' 7993' 16" 9-5/8" 7" Perforation Depth MD ( 7514'-7614', 7656'-7661',7800'-7806',7818'-7844',7866'-7890' Packers and SSSV Type: pkr= BAKER 'FHL'; BAKER 'FB-1' Baker 'FVL' SSSV @ 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: Perforation Depth TVD (ft): 5791'-5865' 5896'-5899', 6000'-6004', 6012'-6031', 6047'-6064' Packers and SSSV MD (ft) pkr= 7357'; 7699' 1807' Tubing Size: 3-1/2" 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 July 26, 2006 Date: Signature Commission Use Onl 18. I hereby rue and correct to the best of my knowledge. Contact: Title: Phone 265-4021 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test ~ Other: 3500 ~V'\~ÙIM.., ~a~~\-- Location Clearance 0 Tubing Grade: J-55 Tubing MD (ft): 7722' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Gary Eller @ 263-4172 Wells Group Engineer Date RBDMS BFL JUL 3 1 2006 Approved by: Form 10-403 Revised 06/2006 APPROVED BY THE COMMISSION Date: ¿oF:" .',.. Subm~ in.Ru licate ?'. ~~ ~ 7' z:-¡.þt.. ConocoPhillips Alaa, Inc. e KRU Z-16 2Z-16 API: 500292136300 Well Type: INJ Anole (â) TS: 41 deo (â) 7514 SSSV Type: LOCKED OUT Orig 6/10/1985 Angle @ TD: 45 deg @ 8150 sssv Completion: (1807-1808, Annular Fluid: Last W/O: Rev Reason: Pull WRP 00:3.500) Reference Loç¡: Ref Loç¡ Date: Last UDdate: 5/25/2006 Last Too: 7875 TD: 8150 ftKB Last Taç¡ Date: 4/612004 Max Hole Anç¡le: 48 deç¡ (âJ 6100 Casino Strino - ALL STRINGS Gas Lift Description Size Top Bottom TVD Wt Grade Thread .ndrellDummy CONDUCTOR 16.000 0 103 103 62.50 H-40 Valve 1 SUR. CASING 9.625 0 4081 3323 36.00 J-55 (7304-7305, PROD. CASING 7.000 0 8102 6214 26.00 J-55 00:5.620) Tubino Strine - TUBING Size Top I Bottom I TVD I Wt I Grade 1 Thread PBR 3.500 1 0 1 7722 I 5943 1 9.30 I J-55 1 8RD EUE (7343-7344, Perforations Summary 003.500) Interval TVD Zone Status Ft SPF Date Type Comment 7514 - 7614 5791 - 5865 4,C-3,C-2,C 100 12 7/10/1985 IPERF 120 deg. phase; 5.5" Hyper Jet II 7656 - 7661 5896 - 5899 UNITB 5 12 7/10/1985 IPERF 120 deg. phase; 5.5" Hyper PKR Jet II (7357-7358, 7800 - 7806 6000 - 6004 A-5 6 4 7/10/1985 IPERF 90 deç¡. ph;4" Hvoer Jet II 00:6.151) 7818 - 7844 6012 - 6031 A-4 26 4 7/10/1985 IPERF 90 deo. ph;4" Hyper Jet II 7866 - 7890 6047 - 6064 A-3 24 4 7/10/1985 IPERF 90 deo. oh;4" Hvoer Jet II Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Injection rJOII Mfr Run Cmnt . ndrellDummy 1 7304 5632 Merla I TMPD DMY 1.5 RM 0.000 0 112/7119971 WI oko Valve 2 (7394-7395, Iniection MandrelsNalves 00:5.620) St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 2 7394 5701 Merla TMPD DMY 1.5 RM 0.000 0 12/7/1997 Wloko Injection 3 7465 5754 Merla TMPD DMY 1.5 RM 0.000 0 12/7/1997 Wlpkç¡ .ndrel/Oummy 4 7679 5912 Merla TMPD DMY 1.5 RM 0.000 0 4/6/2004 Valve 3 (7465-7466, Other (I luç¡s, equip., etc.) - JEWELRY 005.620) Deoth TVD Tvoe Descriotion ID .- .- - 1807 1709 SSSV Baker 'FVL' (LOCKED OUT 4/4/2004) 2.812 TUBING - (0-7722. - - 7343 5662 PBR Baker 3.000 00:3.500, - - 7357 5673 PKR Baker 'FHL' 3.000 10:2.867) - - 7650 5891 PATCH STRADDLE PATCH ASSErv'BLY. SET LOWER PATCH ASSErv'BLY 1.360 - - PATCH - (32.14') BTM STUNG INTO NIPPLE REDUCER @ 7715' RKB, SET (7650-7715, - - 00:2.500) - - UPPER PATCH ASSErv'BL Y WI BAKER 3-1/2" K3 PACK-OFF (33.10') - - BTM STUNG INTO LOWER PATCH TEBACK TOP @ 7683' RKB, PT - - PATCH TUBING ABOVE PATCH ASSErv'BL Y TO 1500#, HELD GOOD, SET 3" DD (7670-7692. SLIP STOP @ 7650' RKB . NOTE TOP OF STRADDLE PATCH @ 7650' 00:3.500) RKB. 7670 5906 PATCH HES PERMANENT PATCH set OVER GLM #4 set 5/12/2004 2.360 7699 5927 PKR Baker 'FB-1' 3.000 7715 5938 NIP RED NIPPLE REDUCER CD' PROFILE) set 4/15/2004 2.250 7715 5938 NIP Camco 'D' Nipple NO GO 2.750 7721 5943 SOS Camco 2.992 PKR 7722 5943 TTL 2.992 (7699-7700, General Notes 00:6.151) Date Note 2/20/199 LEAK Detect shows Bottom of GLM @ 7679' is Leaking; See also WSR 12/13/97; Leak Detect indicates Leak @ Btm Csg Collar NIP REO (âJ 7677' RKB and Upper PKR Leak (âJ 7355' RKB. (7715-7716, 4/16/2005 WAIVERED WELL: T x IA ANNULAR COMMUNICATION 00:2.750) SOS (7721-7722, 00:3.500) TTL (7722-7723, 00:3.500) Perf - - (7800-7806) - - - - - - Perf - - (7818-7844) - - - - Perf = = (7866-7890) - - - - e e 2Z-16 Workover Procedure 1. Set a CA-2 plug in the D-nipple at 7715' MD. Dump sand or carbonate on top of plug. - 2. MIRU e-line. RIH, fire tubing punches through leaking permanent patch and 3Y2" tubing 3. ~~i~~;': :~ent retainer at 7666' MD: ~ì.Nt\).\o ~ \Je> \~ ~ \II , b'b \ ð-Î- 'WJ 4. MIRU coil tubing. Sting into cement retainer at 7666' MD, establish circulation up the IA. ~ (~") Do not exceed formation breakdown pressure. Circulate minimum of 1 0 bbl of cement through the retainer up the IA. Additional cement may be squeezed into the C Sand ~ perfs. Displace cement from coil tubing with seawater. <.J...\'-,"~\~~")\::~.\~'MQ ~~~ ~~o..~\ß., 5. Sti~g out, circulate out remaining cement. POOH.· ~,O ~~ \ '> /: n~ 6. Walt on cement. ~ ~b') 7. Pressure test IA to 2500 psi. Contact Wells Engineer if IA does not adequately test. - 8. MU motor and mill. Drill out cement and the cement retainer at 7666' MD. Continue milling up the permanent tubing patch at 7670'-7692' MD. Continue milling to the top of the CA-2 plug at 7715' MD. POOH, RDMO coil tubing. 9. Pressure test tubing. Run SCMT log from CA-2 plug up to 7000' MD. 10. Perform state-witnessed MIT on IA. Submit a separate 10-403 asking to resume water injection into the A Sand. 11. Pull the CA-2 plug at 7715' MD. 12. Resume water injection into the A Sand when 10-403 has been approved. e tit Review of Sundry Applications 306-252 ConocoPhillips Alaska, Inc. We1l2Z-16 AOGCC Permit 185-109 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to repair the subject well and squeeze a set of perforations. Recommendation: I recommend approval of CPAI' s proposed activities. Discussion: CP AI proposes to squeeze the C Sand perforations through the tubing isolate zone and allow inj ection to resume in a deeper zone. The current wellbore construction should isolate the C Sand from flowing, however due to mechanical problems the C Sand is not isolated and is causing operational problems. The packer set above the C Sand is leaking and allowing gas from the C Sand to enter the IA. Additionally, the tubing across the C Sand interval has developed leaks that affect the water injection into the deeper A Sands. CP AI proposes to perforate the tubing so that they can squeeze the C Sand to isolate it from flowing. They believe this will eliminate their IA pressures and will isolate the C Sand so that it does not act as a thief zone for the water that they are trying to inject deeper in the well. Conclusion: CPAI's proposed activities would place the well in the condition that it is currently intended to be in, C Sand isolated and A Sand receiving water injection. Since the C Sand should be already be isolated the proposed activities are more of a corrective action than a zonal abandonment issue. Therefore, I recommend approving their request. D.S. Roby Reservoir Engineer July 27, 2006 fj)ltv ;je.ç~ f/Ju./- (.,.~ Sdr~ 4r,'/ uoþ g ~~",\~~ ~\\t.c"'--~ ~\O ~~ t()() d- \ h~- 05"" Re: MIT Question on 2Z-16 e e Hi Gary, I believe that "cement packers" are being placed in Prudhoe wells. I look forward to seeing the sundry. Tom Maunder, PE AOGCC Your plan appears appropriate. ..,." f1 \..,,, i;) r:: 00fiÇ' ~. ..AJ\~I~'Ek ! ¡j, "t{ "', c3 (". ,,,L) .¿.,.\.tlr·è'~!: ~ $' '" ~ t ¡, t... Eller, J Gary wrote, On 4/19/20068:18 AM: Tom - Greetings! I have been looking into through-tubing repair options for well 2Z-16 that would eliminate communication to the IA. I have included a brief procedure outline below, but essentially I'm looking at placing a "cement packer" to isolate the C Sand perfs from the IA. Assuming that I can successfully place this cement packer and we can get an acceptable MIT on the lA, my question for you is whether a "cement packer" would suffice for allowing the well to be returned to water injection? Schematic diagram for 2Z-16 is attached. The tubing is sound above 7370' MD, but the FHL packer at 7357' lacks integrity and is allowing formation pressure on the IA. In addition, the AOGCC was notified on 3/5/06 that the well has developed slow IA x OA communication to gas; the well has remained shut in since that time. We're still designing the well repair, but it looks like we'll want to do the following: 1. Set a bridge plug below the #3 mandrel at 7480'. 2. Set a retainer between mandrels #2 and #3 at 7420'. 3. Using coil, sting into the retainer and establish injection into the C Sand. Still discussing whether we would use cement or Thermotech, but the objective would be to establish some squeeze pressure against the C Sand. 4. After squeeze pressure achieved, open the backside and circulate up through the #2 mandrel. The objective is to place a "cement packer" between the #2 and #3 mandrels. 5. After the cement or Thermotech has set up, MIT the IA as per regulation and CPAI policy. 6. Drill out cement and remove plugs from the tubing to once again provide injection access to the A Sand. 7. Conduct a final MIT of the IA. I would like some confirmation that this technique would allow us to resume water injection provided we get a successful MIT on the IA. I did run this past Jerry Dethlefs (NSK Problem Wells Supervisor) and he agreed that it should suffice for resumption of water injection provided we get a solid MIT. If we're not going to be allowed to resume water injection using this technique, then I probably would come up with an entirely different method of securing the well. I look forward to hearing back from you. «2Z-16 wellbore schematic.pdf» J. Gary Eller 10f2 4/25/2006 1:01PM Gas Lift- mdrel/Dummy Valve 1 (7304-7305, OD:5.620) PBR (7343-7344, OD!3.500) PKR (7357-7358, OD:6.151) Injection 'ndrel/Oummy Valve 2 (7384-7395, 00:5.620) Injection 'ndrei/Oummy Valve 3 (7465-7466, 00:5.620) TUBING ._- (0-7722, 00:3,500, iO:2.867) PATCH (7650-7715, 00:2.500) PATCH (7670-7692, 00:3.500) PKR (7699-7700, 00:6.151) NIP REO (7715-7716, 00:2.750) SOS --~ (7721-7722, 003.500) TTL (7722-7723, 00:3.500) Perf (7800-7806) Perf (7818-7844) Perf (7866-7890) Btm Csg Collar 1. Operations Performed: Abandon STATE OF ALASKA REP¿~~KA;~ ;~~~~;S:~~rN ~;~I~~;ION~ ~31JffS> ,~ ,,¡":>;ò~1 0 Suspend 0 Operation Shutdown 0 Perforate 0, :,.Variance D"Änï1tllar Disp. 0 0 RepairWell 0 Plug Perforations 0 Stimulate 0 TimeEXtêhsrdn;pi.jO Other 0 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Status: 5. Permit to Drill Number: Development 0 Exploratory 0 185-109 / Stratigraphic 0 Service 0 6. API Number: 50-029-21363-00 Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 109' 9. Well Name and Number: 2Z-16 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. FieldlPool(s): Kuparuk Oil Pool measured 8150' feet true vertical 6248' feet measured 8150 feet true vertical 6248 feet Length Size MD 103' 1611 103' 3972' 9-5/811 4081' 7993' 711 8102' Plugs (measured) Junk (measured) Burst Collapse TVD 103' 3323' 6214' Measured depth: 7514-7614; 7656-61; 7800-06; 7818-44; 7866-90 true vertical depth: 5791-5865; 5896-99; 6000-04; 6012-31; 6047-64 SCANNED FEB 242005 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7722' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 7357'; 7699' sssv= SSSV SSSV= 1807' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 0 NA Tubinq Pressure 2310 NA Casinq Pressure 1000 NA 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 304-131 WDSPLO Contact Loveland/Gathaman Printed Name MJ Loveland / ~Ie Problem Well Supervisor Signature /1""7~~~ Phone 659-7224 Date ~ -I '1...-0.5- / / RBDMS 8Ft FEB 2 :1 20050 R \ G, \ N A L Form 10-404 Revised 2/2003. SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk We1l2Z-16 (PTD 1851090) Report of Sundry Operations 02/19/05 As per conditions approved on Sundry #304-131, ConocoPhillips Kuparuk injection we1l2Z-16 tubing was patched 5/13/04 to repair a tubing leak at 7677' MD. The patch is 3-1/2", 20-feet long, permanent style. The patch was designed to cover a leaking injection mandrel in the selective completion below the top packer. The top packer is suspected of having failed and is the cause of the failed MIT condition. of the well. The original patch set depths are: Top: 7670' MD Bottom: 7691' MD On 5/16/04 a Slickline test packer determined the top of the patch is leaking and there is still communication into the C sand straddle interval. On 6/18/04 a video verified the top of the patch is leaking. There is no apparent problem with the tubing that is suspected to be the cause of the patch failure. On 6/29/04 "Power Jars" were used in an attempt to fully engage the patch mandrels. On 7/03/04 Pressure testing verified the patch is still leaking. On 12/18/04 Administrative Relief was requested for well operation. On 1/14/05 AIO 2B.002 was received. On 2/19/05 Installed retrievable Straddle patch assembly across original failed patch. Installed straddle patch assembly. Set lower patch assembly (32.14') bottom stung into the nipple reducer @ 7715' RKB, Set Upper patch assembly w/ Baker 3 V2 K3 pack-off (33.10') Bottom stung into lower patch tieback top @ 7683', PT Tubing above Patch assembly to 1500 psi - held good. Set 3" DD slip stop @ 7650' RKB. Straddle patch length 7715' -7650'. On 2/20/05 Turn well over to operations operating under AIO 2B.002 NSK Problem Well Supervisor 07/05/04 ) ~lJ~ìJŒ illJ~ ~~ ') ~[(~ FRANK H. MURKOWSKI, GOVERNOR AIßASIiA. OIL AlQ) GAS CONSERVATION COMMISSION / 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROV AL NO. AIO 2B.002 Mr. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Pulchorage,AJe 99510-0360 RE: KRU 2Z-16 (PTD 185-109) Request for Administrative Approval Approval AI02B.002 Dear Mr. Dethlefs: Per Rule 9 of Area Injection Order ("AIO") 002.B, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants ConocoPhillips Alaska, Inc. ("CP AI")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that CP AI has attempted to perform corrective action on 2Z-16 to restore full integrity, however the work was not successful and CP AI does not propose to con- tinue with the planned repairs. The Commission further finds that, based upon reported results of CPA!' s diagnostic procedures, 2Z-16 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in KRU 2Z-16 is condi- tioned upon the following: 1. Injection is limited to WATER ONLY; 2. CP AI shall monitor and record wellhead pressures (T/I/O) and injection rate daily; 3. CP AI shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 4. CP AI shall perform an MIT -OA every two years to 1800 psi; S'CA" NN" "¡:.;:[) ¡AN 1 4" 2.005 ;;.>',~..., I. ~I.:.::"';'> 't.,) ...:.. ) ADlVITNlSTRATlVE APPROVAL AlO NO. 2B.002 January 14,2005 Page 2 of2 ) 5. CP AI shall perform a leak detection log every two years to demonstrate produc- tion casing integrity; 6. CPAI shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and 7. After well shut in, AOGCC approval shall be required to restart injection. 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 rehearing. A request for rehearing is consid- ered 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Pulchorage, Alask and dated January 14, 2005. iI and Gas Conservation Commission nfZJ. ---~- ~r /~ J Chairman Daniel T. Seamount, Jr. Commissioner "ß~1~;'o;1~:~~l3. . <».". (:. '('~;>.'~=í~~~~ M-;~I¡,~ f>l'~" ..~~.:?~~: ~ \ - ~ ¡~, :/ \~~/../' \ 0\ \' J I C¡o ~. //:jf~B> '. ~.~ /.." . ' . ""ro..1 f~1 '1~' ) ) ConocJPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 18, 2004 R I E DEC 2 1 2004 Alaska Oil Ii Gas Cons. Commission Anchorage Mr. John Norman, Chairman Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Kuparuk Well2Z-16 (PTD 1851090) Request for Administrative Relief to Continue Water Injection Operations Dear Mr. Norman: ConocoPhillips Alaska, Inc., requests approval to continue water injection operations into Kuparuk well2Z-16. This request is pursuant to Area Injection Order No. 2A, Rule 9 Administrative Relief. Kuparuk well 2Z-16 has tubing by inner annulus communication via a failed packer. A combination of leak detect logs and pressure testing of casing strings indicates the well has competent mechanical integrity and can be safely operated. Two barriers have been defined that will prevent an inadvertent release and confine fluids to the approved zones. The attached Technical Justification includes a proposed operating and monitoring plan. Daily monitoring of the wellhead, leak detect logging and casing mechanical integrity tests are proposed to verify the well continues to be safe to operate. Should observations or tests indicate a compromise of well integrity the well will be shut-in and the AGOCC will be notified. There is no source of underground drinking water in this area and so is not endangered by this proposal. If you need additional information, please contact me at 659-7235, or Brad Gathman / MJ Loveland at 659-7224. Sincerely, r'" -Ic{Æ& Jerry Dethlefs Problem Well Supervisor S(;ANNE[) J.AN 4 ¿UOJ Attachments -) ) ConocoP4illips Alaska, Inc. Kuparuk We1l2Z-16 (PTD 1851090) EtVED DEC 2 1 2004 Technical Justification for Administrative Relief Request Alaska Oil & Gas Cons. Commission Well History and Status Anchor~ge Kuparuk River Unit well 2Z-16 (PTD 1851090) was originally completed in June 1985 as a producing well. In 1988 the well was converted to water injection, and in 1991 was converted to MW AG service. In 1997 a tubing leak was detected in the C sand straddle interval at GLM #4 at 7679' MD. In 1998 annular communication was detected between the tubing and Inner Annulus (IA), failing an MITIA attempt in June 1998. The packer was suspected and the well was shut-in. On 3/12/04 a bridge plug was set @ 7378' MD and a successful MIT -Twas performed @ 3100 psi. An MIT -IA failed, confirming the existence of a failed packer at the top of the C sand interval @ 7357' MD. An attempt was made on 5/12/04 to patch the tubing leak in the C sand interval @ 7679' MD with a permanent patch. A defect in the patch prevented the leak from being sealed and the patch cannot be retrieved from the tubing. Well events: 3/12/04: Bridge plug set in tubing @ 7378' MD. MITT passed @ 3100 psi. MITIA failed (upper packer leak). 4/6/04: Tubing plug set in D nipple @ 7715' MD. Leak rate into C sand tubing leak is 1 bpm @ 2400 psi. 4/9/04: Leak detect log verified packer leak; no casing leaks identified. 5/12/04: Attempt to patch tubing across C sand leak @ 7679' MD. Patch failed to set and cannot be retrieved (permanent style). 6/29/04: Attempt to fully set patch with "Power Jars" on Slickline (failed, 5 runs made). 10/12/04: MITOA passed @ 1800 psi. Tested production casing, surface casing and cement shoe to top of cement in OA. 11/21/04: Attempt to straddle leaking patch with straddle patch assembly. Assembly will not pass through permanent patch. Further attempts may be tried in the future to isolate the C sands from inj ection for pattern balancing. Barrier and Hazard Evaluation Tubing: The tubing has integrity to at least the C sand interval below the top packer based on a passing MITT @ 3100 psi. Production casing: The production casing has integrity down to the C sand perforations based on surveillance from the Leak Detect Log, which showed flow passed the top packer and not through casing leaks. In addition, the production casing was tested externally to 1800 psi during the MITOA indicating the upper half is structurally sound (4081' MD to surface casing TD). The 7" 26# J-55 production casing has an internal yield pressure rating of 4980 psi. NSK Problem Well Supervisor 12/18/2004 1 ) ) Surface casing: The surface casing and cement shoe have integrity based on a passing MITOA @ 1800 psi. The 9-5/8" 36# J-55 surface casing has an internal yield pressure rating of3520 psi. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the production casing. The tubing has integrity but the upper packer does not, so wellbore pressure can be observed on the production casing string. Secondary barrier: The surface casing and cement shoe is the secondary barrier. Thermal over- pressure potential will be minimized by daily wellhead monitoring. The Maximum Allowable Operating Pressure (MAOP) will be 1000 psi; any pressure greater than 1000 psi will be suspect and cause corrective action and investigation up to and including a shut-in of the well. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut-in of the well. T/I/O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Approve for water-only injection (no gas or MI allowed); 2. Perform 2-year Leak Detect Log to verify production casing has not developed a casing leak; 3. Perform 2-year MITOA to verify integrity of production and surface casings to OA cement shoe; 4. Submit monthly reports of daily wellhead pressures and injection volumes; 5. Shut-in the well should logs or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Future Patch Options The Engineering staff is proposing further options to isolate the tubing leak into the C sand interval for pattern balancing reasons. Whether the tubing patch is successful or not will not impact this approval request; the same Operating and Monitoring Plan is proposed regardless of the patch outcome. Correspondence with the AOGCC regarding patching will be through the Sundry Notice process. NSK Problem Well Supervisor 12/18/2004 2 SSSV (1807-1808, 00:3.500) Gas Lift andrel/Oummy Valve 1 (7304-7305, 00:5.620) PBR (7343-7344, 00:3.500) PKR (7357-7358, 00:6.151) Injection andrel/Oummy Valve 2 (7394-7395, 00:5.620) Injection andrel/Oummy Valve 3 (7465-7466, 00:5.620) TUBING (0-7722, 00:3.500, 10:2.867) Perf (7656-7661) PATCH (7670-7692, 00:3.500) PKR (7699-7700, 00:6.151) NIP REO (7715-7716, 00:2.750) 50s (7721-7722. 00:3,500) TTL (7722-7723. 00:3.500) Perf (7800-7806) Perf (7818-7844) Perf (7866-7890) ConocoPhillips Alaska, Inc. 2Z-16 API: 500292136300 T SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 7875 Last Tag Date: 4/6/2004 Casing' String - ALL STRINGS Description CONDUCTOR -- P~~.C~¡~~~G Tubing String.. TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7514 - 7614 5791 - 5865 7656 - 7661 5896 - 5899 7800 - 7806 6000 - 6004 7818 - 7844 6012 - 6031 7866 - 7890 6047 - 6064 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type t~ It~ .II18II -- .. I. ... -- ') Well Type: INJ Orig Completion: 6/10/1985 Last W/O: Ref Log Date: TO: 8150 ftKB Max Hole Angle: 48 deg (ã> 6100 Size 16.000 9.625 7.000 Top 0 0 0 Bottom 103 4081 8102 Bottom 7722 TVD 5943 Wt 9.30 Zone :-4.C-3,C-2.C- UNITB A-5 A-4 A-3 Status Ft SPF Date 100 12 7/10/1985 5 12 7/10/1985 6 4 7/10/1985 26 4 7/10/1985 24 4 7/10/1985 KRU 2Z-16 Angle @ TS: 41 deg @ 7514 Angle @ TO: 45 deg @ 8150 Rev Reason: Pull plug, set NIP Red. Patch Last Update: 5/14/2004 TVD 103 3323 6214 Grade H-40 J-55 J-55 Wt 62.50 36.00 26.00 Thread I Grade I J-55 Thread 8RO EUE Type Comment IPERF 120 deg. phase; 5.5" Hyper Jet (I IPERF 120 deg. phase; 5.5 Hyper Jet II IPERF 90 deg. phase;4" Hyper Jet II IPERF 90 deg. phase;4" Hyper Jet II IPERF 90 deg. phase;4" Hyper Jet II TMPD 1.5 V Mfr V Type V OD Latch Port TRO 0 DMY DMY DMY DMY 1.5 1.5 1.5 1 7304 5632 Merla Injection MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO 2 7394 5701 Merla TMPD 3 7465 5754 Merla TMPO 4 7679 5912 Merla TMPD Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1807 1709 SSSV 7343 5662 PBR 7357 5673 PKR 7670 5906 PATCH 7699 5927 PKR 7715 5938 NIP 7715 5938 NIP REO 7721 5943 SOS 7722 5943 TTL General Notes Date Note 12/20/1997 LEAK Detect shows Bottom of GLM @ 7679' is Leaking; See also WSR 12/13/97; Leak Detect indicates Leak @ Btm Csg Collar @ 7677' RKB and Upper PKR Leak @ 7355' RKB. Description Baker 'FVL' Baker Baker 'FHL' HES PERMANENT PATCH set OVER GLM #4 set 5/12/2004 Baker 'FB-1' Camco '0' Nipple NO GO NIPPLE REDUCER ('0' PROFILE) set 4/15/2004 Camco RM 0.000 Date VIv Run Cmnt 12/7/1997 WI pkg RM RM RM Date VIv Run Cmnt 12/7/1997 WI pkg 12/7/1997 WI pkg 4/6/2004 0.000 0.000 0.000 0 0 0 ID 2.812 3.000 3.000 2.360 3.000 2.750 2.250 2.992 2.992 1. Operations Performed: (' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ! i )' L "; ',:, .-) r.J U' 4 ...J \- ,1. . \ Abandon Alter Casing REPORT OF SUNDRY WELL OPERATIQNS¡I' : I ' ,.'" r,. ,t 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Status: 5. Permit to Drill Number: Development 0 Exploratory 0 185-109 I Stratigraphic 0 Service 0 6. API Number: 50-029-21363-00 Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 109' 9. Well Name and Number: 2Z -16 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 8150' feet true vertical 6248' feet measured 8150 feet true vertical 6248 feet Length Size MD 103' 16" 103' 3972' 9-5/8" 4081' 7993' ]I' 8102' Plugs (measured) Junk (measured) TVD Burst Collapse 103' 3323' 6214' Measured depth: 7514-7614; 7656-61; 7800-06; 7818-44; 7866-90 true vertical depth: 5791-5865; 5896-99; 6000-04; 6012-31; 6047-64 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7722' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 7357'; 7699' sssv= SSSV SSSV= 1807' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Nt A \ . Treatment descriptions including volumes used and final pressure: .~ . .ø.. 11 I 13. Representative Daily Average Pr~ñ' or I ection Data Oil-Bbl Gas-Met ater-Bbl Casinq Pressure 7560 1 000 NA NA TubinQ Pressure 2310 NA Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt: 304-131 Contact Printed Name WDSPLO Dethlefs t McConnell Jerry De~~!e~ ;:1~~-7 Form 1 0-404 Revised 2/2003 . Signature Title Phone 659-7224 Problem Well Supe~~~r 7/ØF ORIGINAL ~. SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk We1l2Z-16 (PTD 1851090) Report of Sundry Operations 07/05/04 As per conditions approved on Sundry #304-131, ConocoPhillips Kuparuk injection well 2Z-16 tubing was patched 5/13/04 to repair a tubing leak at 7677' MD. The patch is 3-1/2", 20-feet long, permanent style. The patch was designed to cover a leaking injection mandrel in the selective completion below the top packer. The top packer is suspected of having failed and is the cause of the failed MIT condition of the well. The patch set depths are: Top: 7670' MD Bottom: 7691' MD On 5/16/04 a Slickline test packer determined the top of the patch is leaking and there is still communication into the C sand straddle interval. On 6/18/04 a video verified the top of the patch is leaking. There is no apparent problem with the tubing that is suspected to be the cause of the patch failure. On 6/29/04 "Power Jars" were used in an attempt to fully engage the patch mandrels. On 7/03/04 pressure testing verified the patch is still leaking. ConocoPhillips is reviewing options for additional repairs and/or variances for the well. The AOGCC will be notified should other repairs be attempted. The well will remain shut-in until repairs or approvals are obtained. NSK Problem Well Supervisor 07/05/04 ~ 8;,.' ConocoPhillips Alaska, Inc. 2Z-16 API: 500292136300 I ~ r SSSVType: TRDP - . , Annular Fluid: Reference LOQ: Last TaQ: 7875 Last TaQ Date: 4/6/2004 Casing StrinQ - All STRINGS Description CONDUCTOR .,.,.,.... ..'.'..'. SUR. CASING \ . .. PROD. CASING . Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7514 - 7614 5791 - 5865 7656 - 7661 5896 - 5899 7800 - 7806 6000 - 6004 7818 - 7844 6012 - 6031 7866 - 7890 6047 - 6064 GasLlft.MándrelSNalves St I MD I TVD I Man Mfr I Man Type I 1 7304 5632 Merla TMPD IrUectlönMárjdtelsJ\lâlvøs 5t MD TVD Man Mfr Man Type KRU 2Z-16 Well Type: INJ OriQ Completion: 6/10/1985 Last W/O: Angle (à) TS: 41 deç¡ (à) 7514 Angle (à) TD: 45 deç¡ (à) 8150 Rev Reason: Pull plug, set NIP Red, Patch Last Update: 5/14/2004 SSSV (1807-1808, OD:3.500) Ref LOQ Date: TD: 8150 ftKB Max Hole AnQle: 48 de¡:¡ (à) 6100 Size 16.000 9.625 7.000 Top 0 0 0 Bottom 103 4081 8102 TVD 103 3323 6214 Wt 62.50 36.00 26.00 Grade H-40 J-55 J-55 Thread Gas Lift mdrel/Dummy Valve 1 (7304-7305, OD:5.620) I Grade I J-55 Bottom 7722 TVD 5943 Wt 9.30 Thread 8RD EUE PBR (7343-7344, OD:3.500) Zone :-4,C-3,C-2,C- UNITB A-5 A-4 A-3 Status Ft 5PF Date 100 12 7/10/1985 5 12 7/10/1985 6 4 7/10/1985 26 4 7/10/1985 24 4 7/10/1985 Type Comment (PERF 120 deg. phase; 5.5" Hyper Jet II IPERF 120 deg. phase; 5.5 Hyper Jet II IPERF 90 deg. phase;4" Hyper Jet II IPERF 90 deg. phase;4" Hyper Jet II IPERF 90 deg. phase¡4" Hyper Jet II PKR (7357-7358, OD:6.151 ) --- V Mfr I V Type I V OD I latch I Port I TRO I ~~~ I C~~t DMY 1.5 RM 0.000 0 12/7/1997 WI pkg V Mfr V Type VOD Latch Port TRO DMY 1.5 RM 0.000 0 DMY 1.5 RM 0.000 0 DMY 1.5 RM 0.000 0 Description Date Vlv Run Cmnt 12/7/1997 WI pkQ 12/7/1997 WI pkg 4/6/2004 Injection mdrel/Dummy Valve 2 (7394-7395, OD:5.620) 2 7394 5701 Merla TMPD 3 7465 5754 Merla TMPD 4 7679 5912 Merla TMPD Other?(pIÜas¡:eQulp/;ØtCl)::....'JEWELR¥ Depth TVD Type 1807 1709 SSSV 7343 5662 PBR 7357 5673 PKR 7670 5906 PATCH 7699 5927 PKR 7715 5938 NIP 7715 5938 NIP RED 7721 5943 SOS 5943 TTL ID 2.812 3.000 3.000 2.360 3.000 2.750 2.250 2.992 Injection ~ndrel/Dummy Valve 3 (7465-7466, OD:5.620) TUBING (0-7722, OD:3.500, ID:2.867) Baker 'FVL' Baker Baker 'FHL' HES PERMANENT PATCH set OVER GLM #4 set 5/12/2004 Baker 'FB-1' Cameo 'D' Nipple NO GO NIPPLE REDUCER CD' PROFILE) set 4/15/2004 Camco Perf (7656-7661 ) Date Note 12/20/1997 LEAK Detect shows Bottom of GLM @ 7679' is Leaking; See also WSR 12/13/97; Leak Detect indicates Leak @ Btm Csg Collar (à) 7677' RKB and Upper PKR Leak (à) 7355' RKB. PATCH (7670-7692, OD:3.500) .Ii. ] PKR (7699-7700, OD:6.151) NIP RED (7715-7716, OD:2.750) SOS (7721-7722, OD:3.500) TTL (7722-7723, OD:3.500) Perf (7800-7806) Perf (7818-7844) Perf (7866-7890) ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 . ...~\, r~'l::I'~~. "''1''''" ....:UL- '2004 July 7, 2004 :;;: I~) ,- Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report Of Sundry Operations for ConocoPhillips Alaska, Inc. wells 2Z-16, 3K-17 and 3N-09. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, ~./L~ Jerry Dethlefs Problem Well Supervisor Attachments ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: ..'" ~ - ~ 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 109' 8. Property Designation: Kuparuk River Unit Perforate D Variance 0 Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 185-109 V 6. API Number: / 50-029-21363-00 " 9. Well Name and Number: 2Z-16 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): r-- Suspend D Repair well 0 Pull Tubing D Development Stratigraphic 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): 8150' 6248' Casing Length Size CONDUCTOR SUR. CASING 103' 3972' PROD. CASING 7993' MD TVD Burst Collapse 103' 103 \ 4081' 3323 3520 2020 8102' 6214 4980 4320 16" 9-5/8" 7" ~ ~ ~\(~ 3 Annular Disp. D Other D D D Exploratory D Service 0 Tubing Size: 3-1/2" ~Eœ"IVEJ:'¡7~~' (ft): APR 1 6 2004 Perforation Depth MD (ft): 7514-7614; 7656-61; 7800-06; 7818-44; 7866-90 Packers and SSSV Type: pkr= BAKER 'FHL'; BAKER 'FB-1' SSSV= SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Perforation Depth TVD (ft): 5791-5865; 5896-99; 6000-04; 6012-31; 6047-64 Packers and SSSV MD (ft) pkr= 7357'; 7699' SSSV= 1807' Alaska Oil & Gas Cons. ColTll1iasian 13. Well Class after proposed work: Exploratory D Development D Anchoflltice 0 15. Well Status after proposed work: Oil D GasD WAG D GINJ D Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~//j1arie M~Connell if~ ./ /' Signature Ø~4~~~~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness \-\\\-\ Plug Integrity D BOP Test D Mechanical Integrity Test ~ PlugQed n . \ WINJ 0 / Abandoned D WDSPL D Contact: Title: Marie McConnell or Jerry Dethlefs Problem Well Supervisor Phone: 659-7224 Date: 4/13/04 Location Clearance IS""d~ N3ö~). 51 D Other: \f'J~\t:. Q. Q\-':)L'{ ~ ~v'o<;<t.\-Ut-,,\ "'\\ ()"d'1~D-'~L"<t~\Z: l-\ \ t"'-.O~\"\'t ~~,\-\t---~ ~ ro.~~~ ~\<t~~~'\(t~ BY ORDER OF 1/ ¡ ~ ~ COMMISSIONER~nOMMIS~ 2 .1 .1'2--7 I {/7 n R I r, I N A I SUBMIT IN DUPLICATE Form 10-403 Revised 2/2003 . .. ;. ~ ~ ~ ConocoPhillips Alaska, Inc. Kuparuk We1l2Z-16 (PTD 185-109) SUNDRY NOTICE 10-403 VARIANCE REQUEST 04/13/04 ... \l-..)çç\\ ~~~ ÜL\~\\\ 'ß~c:(\, ~-r s\~c.Jè '\~\'~~l {\<;.C; '\ The purpose of this Sundry Notice variance request is for approval to continue water only injection with a failed MIT. We1l2Z-16 is a water injection well that has been shut-in since '--failing an MITIA on June 30, 1998. Diagnostics found the upper isolation packer at 7375' MD leaking. There is also a tubing leak between the C sand straddle packers at the bottom of the injection mandrel at 7679' MD. The well has tubing by inner annulus communication via the packer and straddle tubing leak. Approval to repair the C sand straddle tubing leak with a tubing patch is requested. A plug will be set in the lower D nipple at 7715' for the tubing MIT. Following a successful MIT, the well will be returned to normal water injection. The tubing MIT will be repeated every 2 years to ensure tubing integrity. Should the MIT fail, the well will be shut-in and repair options evaluated. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Set 20' permanent tubing patch from -7673 to 7693; 2. Perform MIT-T every 2-years with plug @ 7715' as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Well will be used for water injection only (no gas or MI allowed); 4. Injection is limited to A sand only; 5. Submit montWy reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 12/12/03 J" SSSV (1807-1808, OD:3.500) Gas Lift ldrel/Dummy Valve 1 (7304-7305, OD:5.620) PBR (7343-7344, OD:3.500) PKR (7357-7358, OD:6.151) Injection ldrel/Dummy Valve 2 (7394-7395, OD:5.620) Injection ldrel/Dummy Valve 3 (7465-7466, OD:5.620) Gas LIft ldrel/Dummy Valve 4 (7679-7680, OD:5,620) PKR (7699-7700, OD'6.151) PLUG (7715-7716, OD:2.750) TUBING (0-7722, OD:3,500. ID:2.867) Perf (7800-7806) Perf (7818-7844) Perf (7866-7890) ~ ~ ConocoPhillips Alaska, Inc. .,~ ...... ,1 1 - -- KRU i2Zo;1'6<';Y.:';'.;:;;;,'"" , .c',"">',',' API: 500292136300 SSSV Type: TRDP Annular Fluid: Well Type: INJ Orig Completion: 6/10/1985 last W/O: Angle @ TS: 41 deg @ 7514 Angle @ TD: 45 deg @ 8150 Rev Reason: Tag fill, set DMY, Set Plug Last Update: 4/8/2004 Reference log: Last Tag: 7875 Last Tag Date: 4/6/2004 øá:$iñg;$tríng.ÄLL;$.TRINGS, , Description CONDUCTOR SUR. CASING PROD. CASING ;Jublng;$t'dl1g-T.UEJÎNG ,. . ~ .. :~~~I T~P R~tfórätions Sûmmary Interval TVD Zone 7514 - 7614 5791 - 5865 -4,C-3,C-2,C, Ref Log Date: TD: 8150 ItKB Max Hole Angle: 48 deg @ 6100 ,..,', " ." ".. Size 16.000 9.625 7.000 Top 0 0 0 Bottom 103 4081 8102 TVD 103 3323 6214 Wt 62.50 36.00 26.00 Bottom 7722 Wt 9.30 I Grade I J-SS TVD 5943 Status Ft SPF Date 100 12 7/10/1985 5 12 7/10/1985 6 4 7/10/1985 26 4 7/10/1985 24 4 7/10/1985 Type Comment IPERF 120 deg. phasing;5 1/2" Hyper Jet II 'PERF 120 deg. phasing; 5 1/2 Hyper Jet II IPERF 90 deg. phasing;4" Hyper Jet II IPERF 90 deg. phasing;4" Hyper Jet II IPERF 90 deg. phasing;4" Hyper Jet II 7656 - 7661 5896 - 5899 UNITB 7800 - 7806 6000 - 6004 A-5 7818 - 7844 6012 - 6031 A-4 7866 - 7890 6047 - 6064 A-3 Gis 'fliff Ma n drelSlValveS St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Mfr 7304 5632 Merla TMPD DMY 1.5 RM 0.000 0 4 7679 5912 Merla TMPD DMY 1.5 RM 0.000 0 ,lnfection;Mand relsJValves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Mfr 2 7394 5701 Merla TMPD DMY 1.5 RM 0.000 0 3 7465 5754 Merla TMPD DMY 1.5 RM 0.000 0 Øther'{p\U~s, equip;, etc;) ;- JEWELRY Depth TVD Type 1807 1709 SSSV 7343 5662 PBR 7357 5673 PKR 7699 5927 PKR 7715 5938 NIP 7715 5938 PLUG 7721 5943 SOS 7722 5943 TTL General Notes Date Note 12/20/1997 lEAK Detect shows Bottom of GlM @ 7679' is leaking; See also WSR 12/13/97; leak Detect indicates leak @ Btm Csg Collar @ 7677' RKB and Upper PKR leak @ 7355' RKB. Description Baker 'FVl' Baker Baker 'FHl' Baker 'FB-1' Cameo 'D' Nipple NO GO CA-2 PLUG set 4/6/2004 Cameo -- 2Z-16 Grade H-40 J-55 J-SS Thread Thread 8RD EUE Date Vlv Run Cmnt 12/7/1997 WI pkg 4/6/2004 Date Vlv Run Cmnt 12/7/1997 WI pkg 12/7/1997 WI pkg ID 2.812 3.000 3.000 3.000 2.750 0.000 2.992 2.992 ~ ~ Conoc~ ill i pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED APR 1 6 2004 Alaska 0;1 & Gas Cons Commi . . ".,"SSIon Anchorage April 13,2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tl1 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we1l2Z-16 (PTD 185-109). The request regards approval to inject water with a failed MIT. Please call Jerry Dethlefs or myself at 659-7224 if you have any questions. Sincerely, øP/Ø~/~ Marie McConnell Problem Well Supervisor Attachments ORIGINAL RE: Kuparuk 2Z-16 Injector Sundry (PTD 1860770) .~ ~ Subject: RE: Kuparuk 2Z-16 Injector Sundry (PTD 1860770) From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 20 Apr 200408:19:14 -0800 . To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: NSK Problem Well Supv <nI617@conocophillips.com> d 'l:- \ \0 \ <6S--(CJ~ The easiest way for me to answer your question is to provide the attached spreadsheet. This is a summary report of major events on that well. I pulled the entire report that we have in our records. Let me know if this is not what you want. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, April 20, 2004 8:03 AM To: NSK Problem Well Supv Subject: Re: Kuparuk 2Z-16 Injector Sundry (PTD 1860770) Jerry, The proposal looks appropriate. However, I was checking the file and I there is no information for the period 1/24/92 and 12/1/97. The last information says that 2Z-16 had been SI since6/97 due to communication problems. What does your file show regarding activity during between early 1992 and late 19977? Thanks. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: That is correct--we hope to inject water with this well into the A sand using an MIT-tubing to demonstrate integrity. The top packer above the C sand is known to be bad. With a patch over the leak into the C sand straddle we should be able to obtain a good MIT-tubing. However, we haven't run the patch yet so won't know for sure until we do. This well will be on the Monthly Failed MIT report for monitoring. , Jerry -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Tuesday, April 20, 20047:17 AM To: NSK Problem Well Supv Subject: Re: Kuparuk 2Z-16 Injector Sundry (PTD 1860770) Jerry, The date on the form is 4/13. I just looked at it. It appears that there are two leaks and the patch will repair the leak from inside to the C sand, correct?? The leak at the upper packer will still be there. Integrity will be demonstrated via a MIT-T. Tom 10f2 4/23/2004 1 :03 PM Kh: K.UparuJ< 2L.-Iö Injector ~undry (pTU 1860770) ¡-.., ~ NSK Problem Well Supv wrote: Thanks Tom. I didn't realize you just received it--I thought it was sent farther back than that. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 20, 2004 7:06 AM To: NSK Problem Well Supv Subject: Re: Kuparuk 2Z-16 Injector Sundry (PTD 1860770) Jerry, I have the sundry, it was stamped in on Friday. it done today. Tom I would hope to get NSK Problem Well Supv wrote: Tom: Can you tell me the status of Kuparuk injector 2Z-16 Sundry? Marie sent it to you last week or so. The Sundry includes approval to patch and is coming up soon on our schedule. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 2Z-16 Events.xIs Content-Description: 2Z-16 Events.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 2 of2 4/23/2004 1 :03 PM 04106104 04109/04 04115104 BRUSH 0 NIPPLE, SET 2.75 CA2 PLUG 7715' RKB. PULL 1 112 CV FROM STA 4,7679' RKB. RUN 11/2 DV, RM LATCH. ESTABLISH LEAK RATE OF 1 BBL / MIN AT 2400 PSI FOR 20 BBLS DIESEL. [ANN COM ISSUES] LDL COMPLETED. MADE BASELINE TEMP PASS. THEN MADE TEMP PASS WHILE PUMPING DOWN IA TAKING RETURNS TO C SAND FORMATION AS COMPARED TO BASELINE PASS. LOG SHOWED COOLER TEMP ABOVE AND WARMER TEMP BELOW UPPER PACKER @ 7357' RKB. PERFORMED LDL @ LOWEST INJECTI PULLED 2.75" CA-2 PLUG @ 7115'RKB, DRIFT TUBING WITH 2.76" DUMMY PATCH TO 7115'RKB, SET 2.75" X 2.25" NIPPLE REDUCER IN "0" NIPPLE @ 7715'RKB, READY FOR PERM. PATCH [ANN COM ISSUES] d ~-\ ~ \ <tsS - \0\ 5 o~ S- ) ) 05/04/96 10/17/96 11/29/96 02/20/97 04/04/97 04/16/97 04/19/97 05/08/97 06/14/97 06/28/97 08/08/97 09/03/97 09/04/97 11/29/97 12/05/97 12/07/97 12/10/97 12/13/97 12/19/97 12/20/97 12/24/97 06/01/98 06/21/98 09/25/99 04/29/00 OS/23/00 03/12/04 03/13/04 03/23/04 04/04/04 04/05/04 ~ O~ S- SHUT IN C SAND,TAG @ 7872' RKB. WAG TO MI. WAG TO PWI. WAG TO MI. WAG TO SWI. BLIND INSTALLED ON MI LEG. TESTED 7"-3.5" SEAL, HOLDING OKAY. d~-\(, \ <6-S -\()~ TUBING HANGAR TESTED TO 4500 PSI. FIRST TEST FAIU TIGHTEN LDS AND RETEST TO 4500 PSI. 15 AND 30 MIN PRESS 4500 PSI. TUBING HANGAR PASSED TEST. TORQUED LDS ON THE TBG HANGER TO 400# AND TESTED @ 4000 PSI, HELD GOOD. TUBING HANGER TEST TO 5000 PSI. 30 MIN PRESS 4900 PSI. PASS 7" CASING HANGER TEST TO 3000 PSI. 30 MIN PRESS 2950 PSI AFTER TORQUING LDS. PASS PULLED & RESET 1.5",DISPLACED 7"CASING W/195 BBLS OF DIESEL PRESSURE TESTED 7"CASING. BLED DOWN 500# IN 30 MINUTES UNABLE TO BLEED DOWN BELOW 2000#. SUSPECT PACKER LEAK. DETECTED LEAK @ 7302' RKB. SET EXTENDED PKG DV, FAILED TO SEAL. SET PACK-OFF DV, FAILED TO SEAL. SET PES POCKET PACKER IN LEAKING GLM @ 7302' WLM; ATTEMPT TEST CASING, FAILED. IN PROGRESS. PRESSURED 7" FAILED PT WHP FL, FL @ SURF, WHP = 1375 PSI, SIBHP = 3963 PSI (MID PERF). PULLED POCKET PACKER @ 7302' RKB, LEFT GLM OPEN. SET CAT SV IN D NIIPPLE @ 7707' RKB. LOCATED LEAK IN C SAND GLM @ 7677' RKB. IN PROGRESS. SET DV @ 7302' RKB. PULLED, INSPECTED & RESET DVS W/ WI PKG @ 7392',7463', 7677' RKB. C-A2 PLUG SET @ 7707' RKB. TESTED 7" CSG, OK. ATTEMPT TEST TBG, FAILED. SUSPECT UPPER PKR LEAK. IN PROGRESS. UPCOMING WORK TBG TO "C" SD LEAK IN BTM COLLAR OF CSM @ 7677' RKB. 7" CSG LEAK @ UPPER PKR (7355' RKB) "C" SD TO LIFT GAS. ATTEMPTED TO RUN LEAK DETECT LOG. WIRELINE STRANDED @ 6900' ELM. REPAIR WIRELINE STRAND. RD F/ WIRELINE REPAIR, LUBRICATOR INSPECTION & BOP TEST. LEAK DETECT SHOWS BOTTOM OF GLM @ 7677' IS LEAKING. NO ADDITIONAL LEAKS FOUND. PULLED CAMCO A2 PLUG F/ D NIPPLE @ 7707' RKB. PULLED DV @ 7677' RKB & REPLACED W/5'16" RKFS CV. 4 YEAR STATE MIT. ATTEMPTED TO PT 7" ANNULUS, WOULD NOT SUSTAIN ANY PRESSURE INCREASE FAILED. [MIT] PPPOT-TBG PASSED. [WH MAINTENANCE] PPPOT-T TO 5000 PSI PASSED. [WH MAINTENANCE] TAGGED FILL @ 7878' RKB. EST.12' FILL. RAN SPARTEK GAUGES FOR SBHP. 3673# HIGH PRESSURE @ 7845' RKB. [TAG PRESSURE DATA] SET BB PLUG AT 7378' MD USING MICROSMART SETTING TOOL. USED STA 1 GL MANDREL AT 7304' MD FOR TIE IN DEPTH. SET EQUALIZING PRONG IN PLUG. PRONG IS 122" LONG W/1.75 FN. TESTED PLUG TO 3100 PSI. LOST 100 PSI IN FIRST 15 MIN, LOST NOTHING PULLED EQ PRONG FROM BB BRIDGE PLUG. ATTEMPT TO PULL PLUG. DID NOT RELEASE. [ANN COM ISSUES] PULLED PES BRIDGE PLUG @ 7378' RKB, COMPLETE [PT TBG-CSG] LOCK OUT BAKER FVL. [SSSV WORK] RAN FLAPPER CHECKER, LOST PINS ON CHECKER. ATTEMPTED CLOSURE TEST. VALVE APPEARS OPEN. RAN 2.5 CENT, VLV OPEN. FOUND SCALE AT 7669'. RAN 2.6 GAUGE RING AND BRUSH TO 7674' SLM. BROUGHT BACK CHUNK OF SCALE, 2 CHUNKS OF RUBBER AND A SPRING, LODGED ) ) 11/05/89 11/26/89 03/01/90 03/24/90 03/27/90 03/28/90 03/29/90 05/07/90 12/05/91 02/13/92 11/13/92 03/15/93 08/24/93 08/25/93 12/09/93 01/08/94 03/22/94 07/22/94 07/23/94 07/24/94 08/31/94 09/02/94 09/15/94 10/30/94 12/27/94 01/18/95 01/19/95 01/20/95 01/21/95 01/22/95 04/07/95 01/25/96 02/09/96 02/14/96 03/29/96 05/03/96 RAN CVS @ 7392', 7463', 7677' RKB TO OPEN C-SD. SET A-2 BLANKING PLUG IN D NIPPLE TO BLANK A-SD (PREP F/PULSE TEST). COMPLETED SPFO (KDGS) COMPLETED KDGS SPFO. C-SD SPFO COMPLETED. PULLED BP PRONG. UNABLE TO PULL PLUG TO OPEN A-SD. RDFN. PULLED BP PRONG. UNABLE TO PULL PLUG TO OPEN A-SD. RDFN. UNABLE TO PULL BP. PULLED 3 C-SD CVS & RAN DVS TO BLANK OFF C-SD. REDUCED TBG PRESS & PULLED BP. PULLED THREE C-SD DV'S AND RAN CV'S PULLED YESTERDAY TO OPEN C-SD. TAGGED FILL @ 7946',60' BELOW BTM A-SD PERF. COMPLETED WIP. NC SPLIT = 23%177%. CROSS FLOW FROM A TO C. WAG TO MI. WAG TO PWI. WAG TO MI. WAG TO PWI. ATTEMPTED TO CLEAR GAS LIFT LINE BY PUMPING 60/40 METHANOL, PARTIALLY CLEARED. FINISHED CLEARING GAS LIFT LINE. WAG TO MI. MIRU SLlCKLINE. RIH W/BRUSH, BRUSH ACROSS SSSV, COMPLETE CLOSURE TEST, GOOD TEST. WAG TO PWI. SI WELL @ 1100 HRS ON 7-21 FOR 48 HR SPFO. 48 HR SPFO ONGOING. COMPLETED 48 HR SPFO @ 1100 HRS ON 7-23. STARTED 48 HR SPFO @ 1330. COMPLETED SPFO. SHUT-IN FOR DRILLING. ATTEMPTED TBG/FL, SSVWOULD NOT OPEN. WHP/FL, FLUID @ SURF, PRESSURE = 1290 PSI. SET AMERADA AND PANEX @ 7707'RKB FOR 'A' SAND BHP. PULLED CVS @ 7392'RKB, 7463'RKB, 7677'RKB (VERY MINOR EROSION). POCKETS OPEN. SET AMERADA AND PANEX @ 7707'RKB FOR A SAND BHP.PULLED CVS @ 7392', 7463', 7677'RKB (VERY MINOR EROSION.) POCKETS OPEN. 'C' SAND BHP 3309# @ 7564'RKB. IN PROGRESS. C SAND BHP 3309 PSI @ 7564'RKB. IN PROGRESS. PULLED PLUG WI GAUGES A SAND BHP 3345 PSI @ 7707'RKB. REPLACED C SAND CVS @ 7392'RKB, 7463'RKB, AND 7677'RKB. TAGGED FILL @ 7870'R (20' FILL ABOVE BOTTOM PERF.) A SAND PANEX TO BE READ. NO C SAND INTERACTION WITH 2Z-19P LAG MONTHS = PEAK GOR = COMMENT = WAG INSTRUMENTATION FROZEN UP. TRIED ONE OF THE BLANKETS FROM 2A, BUT WRONG SHAPE. WAG TO MI. STATE TEST SAFETY SYSTEM. PRESSURE SWITCH FAILED, TRIPPED AT 700 PSI. SUSPECT GIIWI MODE SWITCH BACKWARDS. WAG TO PWI. SHUT IN C SAND,TAG @ 7872' RKB. ~o~ç d ~-\~ \ 955-\°'\ ) ) 11/22/85 11/23/85 11/24/85 11/25/85 11/26/85 11/27/85 11/29/85 11/30/85 12/01/85 12/07/85 01/01/86 04/07/86 06/13/86 06/15/86 06/16/86 06/20/86 06/24/86 06/26/86 06/29/86 07/04/86 10/29/86 06/15/87 07/22/87 12/23/87 03/13/88 03/16/88 04/30/88 05/31/88 07/02/89 07/07/89 09/10/89 09/11/89 09/13/89 11/04/89 ;) c)~ ç d~- \ \0 \ <6S- \Ol ATTEMPTED TO PULL FISH - GOT 163' OF WIRE. FISH @ 7238'(GLM ABOVE TOP PACKER). WILL CONTINUE FISHING TODAY. ATTEMPTED TO PULL FISH - GOT 91' OF WIRE. FISH @ 7238'(GLM ABOVE TOP PACKER). WILL CONTINUE FISHING TODAY. ATTEMPTED TO PULL FISH - GOT 80' OF WIRE. LATCHED FISH, BUT COULD NOT RETREIVE. WILL CONTINUE FISHING TODAY. LATCHED AND PULLED FISH. WILL CHECK FOR MORE WIRE AND COMPLETE CTU PREP TODAY. PULLED ANOTHER 10' OF WIRE. WILL CONTINUE TODAY. PULLED ANOTHER 39' OF WIRE. SET DVS IN BTM TWO GLMS, TAGGED DV IN TOP C-SAND GLM. READY FOR CTU. TAGGED FILL @ 7798'RKB (7767'WLM) USING WIRE GRAB, BTM PERF @ 7890'. NO INDICATION OF WIRE IN WELL. CTU CO COMPLETE. PUMPED 140 BBLS GD @ 2 BPM, 50 BBLS OF DIESEL FLUSH. MAX DEPTH REACHED 7920'WLM. RECOVERED 197 BBLS. ATTEMPTED TO FLOW TO TANK, NO FLOW APPARENT. PULLED DVS, RAN CVS, TAGGED FILL @ 7874'RKB, BTM PERF @ 7890'. PLAN TO FLOW THE WELL TO TANK FOR CLEAN UP (SINCE WELL DID NOT FLOW FROM A-SAND ALONE). STILL NEED CTU???? MAX ALLOWABLE FILL - 7900'. STARTED INJECTING WATER YESTERDAY. WI STEP RATE TST: MAX WHP = 1600 PSI RATE = 5800 BPD METER MAXED OUT RAN WI PROFILE. A-SAND PERFS 7800'-7806',7818'-7844',7866' - 7890'. PREVIOUS TAG - 7874'RKB (USING TTL), TAGGED FILL @ 7834'. ELIMINATED DYNAMIC RUNS, MADE STATIC STOPS. SHOWS 16% WATER INTO A-SAND PULLED CV'S, RAN DV'S, PT TUBING TO 2200#. READY FOR CTU. CTU CO DELAYED DUE TO BAD GEL. CTU CO COMPLETE. PUMPED 270 BBLS GEL, 116 DIESEL, RECOVERED 586 BBLS. CO TO 8010'. POST CTU TAG @ 8006' RKB, BTM PERF @ 7850'. COMPLETED SRT. BD @ 1750#, SET MWHIP @ 1700#, 2900 BWPD. PULLED TWO DV'S, SET TWO 1/4"OV'S ACROSS C-SAND. A&C SRT COMPLETE. FM BD POSSIBLY NEAR MM, SET WHP @ 1600#, (4800 BWPD). COMPLETED WI PROFILE. A/C SPLIT: A=83%, C=17%. SRT COMPLETED. NO APPARENT FORMATION BREAKDOWN BEFORE MAX'D METER. WHIP=1940#, Q=6321 BWPD. SPFO COMPLETE (KDGS) PICKLED FLOWLINE & TBG W/50 BBLS DIESEL. (TBG 32 BBLS). A/C SRT COMPLETE. NO APPARENT FBD. KDGS SPFO COMPLETED. TAG FILL @ 7992' RKB. (BTM PERF @ 7890') RAN DV IN C SAND MANDREL #3 @ 7463' RKB. RA TRACER/WIP COMPLETE A/C SPLIT 31%/69% PULLED CV @ 7677' RKB, MAJOR EROSION, RAN DV. SI C SD. SRT COMPLETE, NO FBD OBSERVED, MAX WHIP=2310, MAX Q=2712 BEGAN A-SD ONLY SPFO (KDGS). COMPLETED A SAND ONLY SPFO (KDGS). COMPLETED A-SD SRT. APPARENT FMBD @ Q=3460 BWPD, WHIP=1990 PSI. PULLED DVS @ 7302 & 7677' RKB. (PREP F/PULSE TEST) RDFN. ) ) \o~ç d-7- \ <,0 \<65-\0\ Event Date Event Description 06/09/85 OPEN HOLE LOGGING COMPLETED. 07/22/85 TAGGED BTM @8021'RKB, BTM PERF@7890'. RAN AMERADAS, WILL GET PRESSURES TODAY. 07/23/85 07/24/85 07/29/85 07/30/85 07/31/85 08/10/85 08/23/85 08/29/85 08/30/85 08/31/85 09/01/85 09/02/85 09/08/85 09/09/85 09/10/85 09/11/85 09/12/85 09/13/85 09/14/85 09/17/85 09/18/85 09/19/85 10/14/85 10/15/85 10/25/85 11/10/85 11/19/85 11/20/85 11/21/85 WILL GET PREFRAC RATE AFTER 2Z-15. AMERADA RESULTS: DEPTH-WLM UPPER LOWER LUB 23.8 24.2 7345'2156.3 2166.17845' 2333.4 2341.2 LUB 17.921.1 TEMP 150150 NO FLOW TO TANK, SHUT IN TO BUILD UP WHP, BUT NO LUCK. OPENED C SD - PULLED DV'S. ATTEMPTED TO FLOW TO TANKS OVERNITE, WOULD NOT FLOW. PULLED DV & PUMPED METHANOL DOWN ANNULUS. WELL APPEARS TO HAVE UNLOADED. WILL FLOW TO CPF. STRAP DATA: Q=694, FTP=625. CIRCULATED HOT DIESEL & THAWED ANNULUS. ARTIC PACKED. SI WELL. COMPLETED REDUMMYING C SD. PT'D TBG. ALL PRE-FRAC WORK COMPLETED. PUMPED GELLED DIESEL FRAC (DS) W/100 MESH & 20/40 SAND. PUMPED 40 BBLS HOT DIESEL SPEAR W/5% MUSOL, 287 BBLS GD, 756# 100 MESH, 15540# 3-8 PPG SLURRY. POST FRAC ISIP=2110 PSI, FRAC GRADIENT=.704, AVG POST FRAC FLOW - 34 BBLS IN 4.5HRS, Q=181BPD, WHP=500#, WHT=20. THIS IS THE INITIAL 4.5HRS OF FLOWBACK(LE. NOT VERY STABLE, YET). POST FRAC FLOW - 35 BBLS IN 8HRS, Q=105BPD, WHP=400#, WHT=9. POST FRAC FLOW - 25 BBLS IN 8HRS, Q=75BPD, WHP=450#, WHT=12. BROUGHT ON TO CPF, WILL GET TEST TODAY. POST FRAC FLOW -IN TEST -INSTANTANEOUS DATA - Q=240BOPD, GAS=212MSCFD, 883 GOR. TP STABILIZED @ 2770#. ANNULUS PRESS REMAINED @ 0#. POST FRAC FLOW - KDGS TEST RESULTS, Q=214BOPD, 1286 GOR. STOPPED FLOWING TO PRODUCTION LINE. UNABLE TO PUMP DIESEL DOWN HOLE TO CHECK SSSV. WILL PUMP METHANOL IN CASE THERE IS AN ICE PLUG. PUMPED 1 BBL MEOH DOWN TBG, STILL PRESSURED UP. DID NOT FLOW TO TANK, POSS.ICE PLUG. STILL WILL NOT FLOW. OPEN TO TANK, STILL WILL NOT FLOW. TAGGED ICE/HYDRATES @ 600', PUMPED METHANOL DOWN LAST NIGHT. WILL ATTEMPT TO GET THRU TODAY. COULD NOT PUMP METHANOL DOWN, LOCKED UP. WILL USE CTU WHEN AVAILABLE. CTU TO CLEAR ICE PLUG COMPLETE. PUMPED 55 BBLS METHANOL @ 1/2 TO 1 BPM. CLEARED ISOLATED OBSTRUCTIONS FROM 600' TO 1300'. FTP WENT FROM 100# TO 900# WHEN GOT PAST 1280'(LE. BROKE THRU). DISPLACED CTU WITH 18 BBLS OF DIESEL. KDGS TEST RESULTS: Q= 719 BOPD, 2120 GOR. FTP= 490#. ICE PLUG GONE. POST FRAC WELL TEST. WILL PULL OIL SAMPLE TODAY. DEGRADATION OF TEG VIA PKR LEAK. LAB ANALYSIS: DATE % TEG 9/2 57.5 9/7 30.2 J. OTTASON HAS RECOMMENDED TO OPERATIONS TO INCREASE TEG CONTENT IMMEDIATELY. ATTEMPTED TO PULL DVS, HIT ICE PLUG. RIGGED UP HB&R, PUMPED 55 BBLS HOT DIESEL BEFORE WELL PRESSURED UP TO 3500#. POSS PUSHED ICE PLUG TO D NIPPLE? WILL LEAVE THERE TO THAW AND ATTEMPT AGAIN TODAY. PULLED DVS, RAN CVS, TAGGED FILL @ 7806', BTM PERF @ 7890'. DID NOT GET TO RIG UP FOR TAG DUE TO UNIT AVAILABILITY. TAGGED FILL @ 7771 WLM = 7802 RKB, BTM PERF @ 7890 RKB THEREFORE NEED CTU PULLED C SD CV'S. RAN BTM DV & GOT STUCK. DROPPED CUTTER BAR & RETRIEVED. RETRIEVED FISH. RAN TOP DV & GOT STUCK, PARTED WIRE. WIRE GRAB ON WIRE BALL, APPROX 300' ABOVE TOP DV. ATTEMPTED TO PULL FISH - GOT 25' OF WIRE. FISH @ 7342'(TOP C-SAND GLM). WILL CONTINUE FISHING TODAY. c' .. ) ) SEI¥I' BY :AP[LO /ILASKA To: Blair Wondzell From: Eric Zuspan Fax,' Pages: 1 Pbene~. 793-1226 Data'. 11/2g/97 Re', 1997 MIT's CC: [] Urgent [] For Review [] Please Comment [] Please Reply [] Please Recycle · Comment~; Blair, Here is details on the remaining MIT's for 1997. 1Y-06 was sidetracked in '91(1Y-O6A) and is now a producer, 2Z-16 has been SI since 6/97 for communication problems. I have included the failed MIT. 3Q-15 should be tested in the next week or so. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO Atasko, inc. FIELD / UNIT 1 PAD: COMMENTS: Well SI 6/97 due to TBG X 7" corem. Current/y evatuatJn9 patch procedures. Kuparulc/2.Z 1,750 DATE: C~IENTS: ~ENTS: C-'~e~MENTS: I II I i I COMMENTS: [ I I It [ II [I I II TBGI. INd. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER [NJ_ N = NOT INJECTING TESTTYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE .ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST DisbibutJan: orig- Well File c- Operate[ c- Datal~se c - Trip Rpt File c- Inspector OPERATOR REP SIGNATURE: Eric Zuspa~, ANNULAR FLUID: P.P.G. Grad. DIESEL I °'~ GLYCOL 0,00 SALT WATER 0,00 DRILLING MUD OTHER 0,00 WELL TEST: Lnitial 4 - Year X Workover Other ,r'~-,&'"'. ~~AOGCC REP SIGNATURE: 3A-06 MIT.xls (Rev 9/17/96) STATE OF ALASKA ALASKA OIL AND GAS CC SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well _ Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1291' FSL, 327' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1561' FNL, 1274' FWL, Sec. 11, T11N, R9E, UM At effective depth 1305' FNL, 1032' FWL, Sec. 11, T11N, R9E, UM At total depth 1236' FNL, 970' FWL, Sec. 11, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8150' feet 6247' feet Effective depth: measured 8018' feet true vertical 6153' feet Casing Length Size Structural Conductor 1 0 3' 1 6" Surface 4 0 81 ' 9 5/8" Intermediate Production 8102' 7" Liner Perforation depth: Plugs (measured) None Junk (measured) None Cemented 250 Sx PFC 1100Sx CS III & 450 Sx CS II 435 Sx Class "G" & 250 Sx AS I 6. Datum elevation (DF or KB) 154 RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-16 9. Permit number/approval number 85-109 10. APl number 50-029-21363 11. Field/Pool Kuparuk River Oil Pool RECEIVED JAN 2 8 3992 Alaska Oil & (Jas Cons. ~,umrnissi0n Measured depthArlC~rru~ertical depth 115' 115' 4081 ' 3322' 8102' 6213' measured 7514'-7614', 7656'-7661' 12 SPF 90 deg phasing 7800'-7806', 7818'7844', 7866'-7890' 4 SPF 90 deg phasing true vertical 5790'-5864', 5893'-5898', 5998'-6002', 6011'-6029', 6045'-6062' Tubing (size, grade, and measured depth) 3 1/2" J-55 to 7712' Packers and SSSV (type and measured depth) Baker FHL Pkr @ 7355', Baker FB-1 Pkr @ 7697', Baker FVL SSSV ~ 1805' 13. Stimulation or cement squeeze summary Converted well from water injector to water alternating gas (WAG) injector. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that th.e~ fore, going ReDresentative Daily Average Production or Inie~ion Data OiI-Bbl ~s-Mcf Water-Bbl CasingPressTubingPress 0 0 5000 1300 2200 0 1200 5000 1850 3200 16. Status of well classification as: Oil _ Gas _ Suspended Service IWAG Ini --orm 10-404 Rev 06/15/88 is true and correct to the best of my knowledge. Title ' OPERATIONS ENGINEER Date SUBMIT IN DUPLICATE N Z S E 0 T L N A L E T 1 B PR 5 B PR 7 I3 PR i0 13 .PR 12 B PR t3 B PR 18 B PR 19 13 PR 20 13 PR 21 13 PR 29 13 PR TOTALS' W Z S E 0 T L N A L E T 2 B MI 3 B PW 4 B PW 6 B PW 8 B PW 9 I~ PW 11 B PW 14 B PW 15 B PW 1,5 B MI TOTALS: KDgS MORNINg WELL REPORT FOR 12/15/91 DRILLSITE 2Z PRODUCTION WELL STATUS ,~ '-' ~A= LiFT STATUS 7" 10" TP TT WC H2S CS~ CSg PSI CHK DEg % PPM PS! PSI 395 !76 131 57 !80 1350 250 260 176 132 70 140 1470 970 247 i76 87 23 40 900 720 400 !76 129 15 70 1050 1000 247 176 68 49 0 900 720 244 176 113 80 40 1040 540 248 176 139 82 55 1070 1000 295 176 142 90 146 1450 760 258 176 120 69 90 1200 700 244 !76 135 91 0 1670 200 246 176 62 31 10 500 200 SI CN OAS INd ^It ]'EMP METER VOLS LI DEg READINg MSCF EB 27 1473 0 0 62 1141 0 0 60 2277 184 0 62 1521 0 0 36 2362 952 0 44 1907 295 0 65 478 0 0 12 9985 600 0 36 6868 380 0 34 9531 148 0 0 24047 29 0 2588 0 INJECTION WELL STATUS INdECTION VOLUME ALLOW ACT 7" i0" INJ INO TT CSg CSQ PSI PSI DEg CH½ PSI PSI 3900 3426 88 20 900 0 2500 0 153 16 670. 510 2500 2496 155 10 740 650 2500 2364 155 40 1200 i000 2500 1898 141 28 900 630 2500 2360 156 66 1370 680 2500 2031 157 -20 1220 700 2500 0 155 30 1000 730 2500 2017 147 73 1370 850 3900- 35~4 .87 ~5 130 400 :~, _ /.SWI' INd INd METER VOLS VOLS READINg BBLS MMSCF 3603 0 14. 136 4316 829 0.000 6019 5649 0.000 8942 6198 0.000 6472 5207 0.000 1998 3866 0.000 7783 5980 0.000 5058 522 0.000 3957 5241 0.000 2740 0 3.247 0 + PWI' 33492 = 334-92 17.383 P ,:", {; F' i. H M 0 R I D S N E O©O0 0 O03D 12 000,D 0 ,-JO00 (} ,7? 0000 0 -} 9000 ,2 ", OOOO 0 0000 0 0000 0 0045 12 13 0000 0 0 S/I C H M 0 R I C, S N E 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action 2Z-16 30-07 Conv to WAG Inj Conv. to Wtr Inj Anticipe, ted Start Date December, 1991 December, 1991 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) RECEIVED Alaska Oil & Gas Cons. Corrlmission A~chora[je ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Ar:',33-c~00%C APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X 2. Name of Operator ^RCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 _ Plugging Pull tubing _ Type of Well: Development Exploratory Stratigraphic 1291' FSL, 327' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1561' FNL, 1274' FWL, Sec. 11, T11N, R9E, UM At effective depth 1305' FNL, 1032' FWL, Sec. 11, T11N, R9E, UM At total depth 1236' FNL~ 970' FWL~ Sec. 11~ T11N, R9E~ UM 12. Present well condition summery Total Depth: measured 81 5 0' true vertical 6 2 4 7 Effective depth: measured 8 01 8' true vertical 61 5 3' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Operation Shutdown _ Re-enter suspended wall_ Time extension _ Stimulate _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) feet Plugs (measured) feet None feet Junk (measured) feet None Length Size Cemented RKB 109 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-16 feet 9. Permit number 85-109 10. APl number so-029-21 363 11. Field/Pool Kuparuk River Field KuR~rk[k .Biy..e[ .Oil _Pool Alaska Oil & Gas Cons. Commissior~ Measured'~ra'~e vertical depth 1 03' 1 6" 250 Sx PFC 1 1 5' 1 1 5' 4081' 9 5/8" 1100SxCSlII & 4081' 3322' 450 Sx CS II 81 02' 7" 435 Sx Class G 81 02' 621 3' 250Sx AS I measured 7514'-7614' , 7656'-7661' 12 SPF 90 deg phasing 7800'-7806', 7818'-7844', 7866'-7890' 4 SPF 90 deg phasing true vertical 5790'-5864', 5893'-5898', 5998'-6002', 6011'-6029', 6045'-6062' Tubing (size, grade, and measured depth) 3 1/2" J-55 to 7712' Packers and SSSV (type and measured depth) Baker FHL Pkr ~ 7355', Baker FB-1 Pkr ~ 7697'~ Baker FVL SSSV ~ 1805' 13. Attachments Description ~.u~mmary of proposal _ Detailed operation program X BOP sketch _ ,Convert well from water' injector~water alternating gas ('~VAG) injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: December 1991 Oil __ Gas __ Suspended _ 16...1~ proposal~was ver~ally approved Date approved Service Water alternating .~as in)ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR GONIVIISSION USE ONLY" Conditions of approval: Notify Commission so representative mey witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form require 10-/'~0~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No. · 0o~¥ / Commissioner Da~ i~'-~rJ-¢I Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE ARCO Alaaka, Inc Date: Subject: From/Location: Telephone: To/Location: Internal Corraapom,,~nca November 27, 1991 File Code: Well File: 2Z-16 Well 2Z-16 Conversion from Water to MWAG Injection Eric Paerels 263-4339 C. House / R. SIoan N S K- 1 4 As a follow up to our conversation, Well 2Z-16 should be converted to MWAG gas injection on December 3rd, 1991. The well is presently part of the 1Y/2Z bounded waterflood area. Well 2Z-16 was included in the original 1Y/2Z SSEOR Project AFC #471488 as a potential MWAG injector. The necessary metering and piping was installed in early 1988. Based on my conversation with Carl Montgomery no charges, other than normal WAG conversion costs, will be incurred to convert this well to MWAG injection. No ballot to the working interest owners is required to convert a well from water injection to MWAG injection if no costs are associated with the conversion. A verbal Sundry Approval has been obtained from the State of Alaska, a copy of which is attached. Well 2Z-16 is fitted with a FMC Gen III 5000 psi tree~ The injection string is made up with standard 8 round couplings, not AB modified. An initial estimate indicates that the well will be on MI for 40 days, at an injection rate of 10 MSCFD, before conversion back to water injection. Notification for conversion back to water injection will be .done via the weekly Wellwork Priority List. Please contact me at the above number if you have questions regarding this conversion. Operations Engineer Attachments cc: W.H. Carter M. Pearson G. K. Phillips S. M. Renke D. A. Toth S. W. Bokhari D. A. Swauger C. Crabtree / J. Mooney J. Snell / (Vacancy) ARCO ~ I~. b a 8ubsJdbuy c~ Atlantic ~ ~ AI:~G-~001-A ATO-1120 ATO-1176 ATO-1170 ATO-1126 ATO-1192 ATO- 1202 ANO-912 NSK-47 NSK-14 (Fax'd~ to NSK / / By__) WELL WATER INJECTOR 2Z-16 APl # 500292136300 SURFACE LOCATION: 1291' FSL, 327' FEL, SEC 11, T11N, R9E, UM TOP KUPARUK: 1561' FNL, 1274' FWL, SEC 11, T11N, R9E, UM DEPTHS: REFERENCED TO (7 RKB Tree: FMC Gen III (3-1/8") ALL DEPTHS MD-RKB (GL-RKB=42') CORRECTION FROM LAST WSR = 29' J L 16": 62.5# H-40 @ 103' 9.625" 36# J-55 @ 4081' PBR BAKER @ 7341' PKR BAKER FHL @ 7355' C2 C3 BLAST JOINTS SPUD: 06/02/85 COMPLETION: 07/09/85 SSSV' BAKER FVL 2.81' 1805' GLMI: 7302' MERLA TPDX 1.5" DV GLM2: 7392' MERLA TPDX 1.5" CV GLM3: 7463' MERLA TPDX 1.5" CV GLM4: 7677' MERLA TPDX 1.5" CV PKR BAKER FB-1 NOGO CAMCO "D" 2.75 SHROUT CAMCO B A6- A5 A4 7": VOLUME: 0.0383 BBL/FT 7697' 7707' 7712' 2~ J-55 @ 8101' PBTD: 8018' 3.5" 9.2# J-55 EUE 7713' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACF:IOSS KUPARUK = 43 DEGREES MAX. HOLE ANGLE =48 DEGREES @6103' VOLUME TO TOP PERF -- 70 BBLS 7514'-7614' 12 SPF C1234 7656'-7661' 12 SPF B 7800'-7806' 4 SPF A5 7818'-7844' 4 SPF A4 7866'-7890' 4 SPF A3 LAST TAG DATE: 03/28/90 7946' REVISION: 03/12/91 STATE OF ALASKA .... -ALASKA tjIL AND GAS CONSERVATION C~JMMISSlal~ W.=LL COMPLETION OR RECOMPLETION REPORT Classification of Service Well 1. Status of Well REV IS ED OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ]~ WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-109 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-21363 4. Location of well at surface 9. Unit or Lease Name 1291' FSL, 327' FEL, Sec.ll, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1561' FNL, 1274' FWL, Sec.ll, TllN, R9E, UM 2Z-16 At Total Depth 11. Field and Pool 1236' FNL, 970' FWL, Sec.ll, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri var 0i 1 Pool RKB 109' ADL 25646 ALK 2577 12. Date Spudded 131 Date T.D. Reached 1'4. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 06/02/85 06/10/85 06/10/85' N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional 'Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8150'MD, 6247'TVD 8018'MD, 6153'TVD YESX~] NO [] 1805 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 255 sx PFC 9-5/8" 36.0# J-55 Surf 4081' 12-1/4" 1100 sx CS Ill & 450 s; CS II 7" 26.0# J-55 Surf 8102' 8-1/2" 435 sx Class G & 250 ix AS I _ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 3-1/2" 7712' 7355' & 7696' 7514 ' -7614 'MD 5790 ' -5864 'TVD 7654 '-7661 'MD 5893 ' -5898 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7800'-7806'MD 5998'-6002'TVD See attached Fracture Stimulation reporl; 7818'-7844'MD 6011'-6029'TVD dated 8/22/85_, for fracture data. 7866 ' -7890 'MD 6045 ' -6062 'TVD 27. ~/,~ PRODUCTION TEST Date"Ci'r'st Production I Method of Operation (Flowing, gas lift, etc.) I Date of Tes't HOurs Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co, r) Press. 24-HOUR RATE ~ 28. ' CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None t'?, '~' '-'':~ , *Note: Tubing was run & the well was perforated 7/10/85. . . Ill~W'%~'' 141, _l~,&&l I Form 10~,07 Rev. 7-1-80 WC5/14 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat(~ ~ C~_.Ob 'G'IC MARKER§ ~.: .~ ;.. . , : .. , . -... . ' · . · NAME" ~ Include inter~;al tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand .7510' 5787' N/A '. Base Upper Sand 7616' 5865' Top Lower Sand 7788' 5989' Base Lower Sand 7966' 6116' .. 31. LIST OF ATTACHMENTS Fracture Stimulation Summary (dated 8/22/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~ ~ ~/../~_/-)-¢_J_~/ Title Associate Engineer Date ~,~-4 INSTRUCTIONS General: This form is designed for-submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification ·of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 ,, % Bedl,~n Frae I~ork (aouro) (l~aCe) :, ZIIC) (: T ~ ' Pu~ped Lo&d ~o r.~over (~OTE~ Loed c~ recover Job complete st ~02 8/28/8~ CONG itt ~{~{~ 0 ~~ ~S0 ~ lll~I I~ ~~ ) / ~ C O~ ~o fluid-volum{ only.) S IGN~: 0 Mr. C. May 27, Page 3 V. Chat+~rton 1986 Well Number 1L-5 1R-3 1Q-!3 Well Number 1Y-2 1Y-8 1Y-12 1Y-15 .Well Number 2W-2 2W-8 2W-10 2W-!4 Date of I Profile 10/2~85 ........ 3/25/86 '- ........ L .. £ k_ ........ . 11/19/85 3/21/86 11/16/85 3/18/86 Date of Initial Injection Date of Injection Profile 3/30/85 · 8/7/85 3/30/85 8/8/85 3/30/85 8/10/85 10/28/85 3/23/86 Date of }nitial Injection Date of Injection Profile 11/15/85 3/26/86 11/15/85 3/27/86 1/13/86 3/28/86 11/15/85 3/29/86 11/15/85 3/31/86 Well Number Date of Initial Injection Date of Injection Profile 2X-1 11/4/85 3/22/86 2X-2 11/19/85 3/14/86 2X-3 11/4/85 3/23/86 2X-6 11/4/85 3/21/86 2X-7 11/4/85 3/23/86 Well Number [lq ~':~-J~ ~ 2Z-3 2Z-14 ~ 2Z-16 Date of Initial Injection Date of Injection Profile 11/4/85 4/3/86 12/2/85 4/2/86 12/1/85 4/6/86 VLF'pg'O051 RECEIVED MAY: 0 oil & c~ Cons. ARCO Alaska, Inc...._~. Post Office ( ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kupa-uk River Field: on the Well Action Date Performed 1L-1 Conversion 1L-7 Conversion lQ-2 Conversion 1Q-7 Conversion 1Q-11 Conversion 1Q-13 Conversion 2B-5 Conversion 2B-9 Conversion 2C-1 Conversion 2C-3 Conversion 2C-6 Conversion 2C-8 Conversion 2D-2 Conversion 2D-7 Conversion 2D-11 Conversion 2D-14 Conversion 2F-1 Conversion 2F-2 Conversion 2F-13 Conversion 2F-14 Conversion 2G-3 Conversion 2G-3 Conversion 2G-5 Conversion 2G-7 Conversion 2G-10 Conversion 2~-12 Conversion 2G-16 Conversion 2U-3 Conversion 2U-4 Conversion 2U-7 Conversion 2U-16 Conversion 2W-2 Conversion 2W-4 Conversi~on 11/1 11/1 11/1 11/1 11/1 11/1 11/2 11/2 11/1 11/1 11/1 11/1 11/2 11/2 11/2 11/2 11/2 11/2 11/2 11/2 11/1 11/1 11/1 11/1 11/1 11/1 11/1 11/1 .11/1 11/1 11/1 '11/2 8/85 8/85 7/85 7/85 7/85 7/85 3/85 3/85 9/85 9/85 9/85 9/85 0/85 0/85 0/85 0/85 1/85 1/85 ~/85 1/85 4/85 4/85 4/85 4/85 4/85 4/85 4/85 RECEIVED 6~85 6/85 JAN.8 6/85 5/8~ 0U & Gas ~ns. ~mml~sion 2/85 ARCO Alaska, Inc. is a Subsidiary of AllanllcRichlieldCompany M r. C. V. Chatterton, Chairman Well Action Date Per fo rmed Page 2W-5 Convers 2W-8 Convers 2W-1 0 Convers 2W-1 4 Convers 2W-16 Convers 2X-2 Convers 2X-4 Convers 2X-5 Convers 2Z-9 Convers 2Z-11 Convers 2Z-1 4 Convers 2Z-16 Convers on on on on · on · on 11/22/85 11115185 11/15/85 11/15/85 11/22/85 11118185 11118185 11118185 11/17/85 11/17/85 11117185 11/17/85 if you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address Po O. BOX 100360, ANCHORAGE, ALASKA 9 9 5 1 0 4. Location of Well SURFACE LOCAT ION' T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 09 ' (RKB) 12. 1291' FSL, 327' FEL, SEC. 11, 7. Permit No. 85-109 8. APl Number 50- 029-21363 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2Z-16 11. Field and Pool KUPARUK RIVER FI ELD I 6. Lease Designation and Serial No. KUPARUK RIVER O I L ADL 25646 ALK 2577 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 17, 1985 Kuparuk well 2Z-16 was converted producer to a water injector well as part of the full waterflood conversion effort. Water is being injected "A" and "C" sands. from a field into both the RECEiVEP Alaska 0il & Gas C;)ns. U.,,r,~-.:~ ..... 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-/'~-~J~ (~~ Title K! I PARI IK Date The space below for Commission use OPERAT IONS COORD I NATOR_ Conditions of APproval, if any: 17_/!8/85 By Order of Approved by COMMISSIONER the Commission Date Form 10403 F~p~, 7-1 -R(~ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 -_ RETURN TO: ARCO ~'* *"~<-- '* ALASKA, INC. KUPARUK OPERATIONS ENGINEERING R/~CORD$' CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5421 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF T~IS TKANSMITTAL. FINALS/ SCHL/ CEMENT <ONE * OF EACH> ~lA-3/ CEMEN~ EVALUATION TOOL -lB-4~ .CEMENT EVALOATION TOOL ~lR-9/ CET LOG J1R-i~//CET LOG -'IR-1 CET/CEL ~lR-12/ CET LOG X~2A-13- CBL/VDL \2A-13-/ CET/CEL o2U-3~ CEMENT EVALUATION TOOL ~2U-10 / CEMENT EVALUATIO~ TOOL ~2Z-13/ CET LOG ~2Z-14~ C~T LOG '~2Z-15~ CET LOG -~2Z-16-- CET LOG ~3B-4"~. CEMENT EVALUATION TOOL %3B-12~ CET LOG ~B-12~ CEMENT EVALUATION LOG W/ AC ~3B-16/CEMENT EVALUATION TOOL ~3C-9/ CET LOG ~3C-10~ CET LOG 05-04-85 RUN #1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN #1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN %2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN *#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-8011 05-31-85 RUN #1 6000-7743 07-14-85 RUN #2 6139-8089 07-06-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 kUN #1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DRILLING*BL L. JOHNSTON MOBIL NSK CLEkK*BL DISTRISUTION: ¥~. PAMHEK hXXON PHILLIPS OIL J. RATHMELL ~- u=~ l.,~p,S CO""-' sohio UNION VAULT/~0' FI LMS ,ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Hell Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells- 2Z-16 L1-1 If you have any questions, please call me at 263-4944. Sincerely, d. ~ruber Associate Engineer JG/tw GRU5/LIO Enclosures RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~-- STATE OF ALASKA ALASKA £.,.._ AND GAS CONSERVATION CO~'--IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-109 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21363 4. Location of well at surface 9. Unit or Lease Name 1291' FSL, 327' FEL, Sec.11, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number. 1561' FNL, 1274' FWL, Sec.11, T11N, RgE, UM 2Z-16 At Total Depth 11. Field and Pool 1236' FNL, 970' FWL, Sec.11, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBJ ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 06/02/85 06/10/85 06/10/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 1 21. Thickness of Permafrost 8150'ND,6247'TVD 8018'MD,6153'TVD YES I-~X NO [] 1805 .~-'f_e'~;l~DI 1500' (approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 255 sx PF "C" 9-5/8" 36.0# J-55 Surf 4081' 12-1/4" 1100 sx CS III & 450 s) CS II 7" 26.0# J-55 Surf 8102' 8-1/2" 4:)5 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7890' - 7866' 3-1/2" 7712' 7355' & 761)6' 7844' - 7818' w/4 spf, 90° phasing 7806' - 7800' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7661' - 7654' N/A 7614' - 7534' w/12 spf, 120° phasing 7554' - 7514' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD m~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (tort) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED 0CTI !985 Alaska 0il & Gas Cons. 60r,~rnissi0r, Anchorage Form 10-407 w NOTE: Tubing was run and the well was perforated 7/10/85. TEMP2/WC30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . ; · NAME Include interval teste~l, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7510' 5787' N/A Base Upper Sand 7616' 5865' Top Lower Sand 7788' 5989' Base Lower Sand -7966' 6116' 31. LIST OF ATTACHMENTS Well Hi s~.ory (completion de,ail s) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ _~/.~ Title Associate Engineer Date //- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). : Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng' and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel~rt" on the first Wednesday afler 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 lenglh 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 reportmg the entire operalion d space is available. I Accountlng cost center code District County or Parish ISlale Alaska North Slope Borough J Alaska Field Lease or Unit I"'/ell no. Kuparuk River ADL 25646 I 2Z-16 Auth. of W.O. no. Title AFC 603481- -- Completion wws f;1 Operator ARCO Alaska, Inc. Spudded or W O. begun Complete AP~ 50-029-21363 A.R.Co. W.I. 56.24% Date 7/8/85 Iotal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our ~Prior slefus if a W.O. I 1200 hrs. Date and deplh Complete record for each day reported as of 8:00 a.m. 7/09/85 7/10/85 7" @ 8101' 8018' PBTD, Perf'g 9.5 ppg Brine Accept ri~ @ 1200 hrs, 7/8/85. ND tree, NU & tst BOPE. RU WL, RIH w/4" csg guns, 4 SPF, 90° phasing, perf f/7890'-7866', 7844'-7818' & 7806'-7800'. RIH w/5½" csg guns, 12 SPF, 120° phasing, perf f/7661'-7654' & 7614'-7534'. 7" @ 8101' 8010' WLM, ND BOPE 9.5 ppg Brine Perf w/5½" guns, 12 SPF f/7514'-7554'. Rn 6.125" GR/JB to 7514'; would not go. Rn 5.95" GR/JB to 8010' PBTD. Rn Bkr FB-1 pkr & set @ 769~[. Rn 3½" compl string. Stab in to btm pkr, space out, drop ball, lnd tbg. Set top pkr. Shear PBR. Tst top pkr; OK. Set BPV. 7/11/85 7" @ 8101' 8010' W-Lll, ~ Crude w/diesel cap ND BOPE, NU & tst tree. Displ well to crude. Tst SSSV. RR @ 1200 hrs, 7/10/85. 8018' PB~ I Released rig Date IKind of rig 1200 hrs. 7/10/85 J Rotary Classifications (oil, gas, etc.) Type comolel~on (smg~e. dual. etc.) Oil ~ Single Producing method ~ Official rese~oir name(s) Flowing ~ Kuparuk Sands Potential test data Well no. Date Reservoir Producing Inlerval Oil or gasTest lime Production Oil on lest !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 c~. Signat~.~l~ ~.~ -.~. IDate ITM 7/25/85 Drilling Superintendent For form Prep .... i .... d dislr,bul, .... W.S. OON ,UUJ----"----' RECEIVED see Procedures Manual. Section tO. Drilling, Pages 86 and 87. AR3B-459-3-C /as they are o~par~d lot each well, / ~ncnorag~ ARCO Alaska, Inc. Post Office [~,,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED SEP 0,1 5 0~ & 6~s Co~s. Commission Ar~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,.AND GAS CONSERVATION C( MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, ;[nc. 3. Address P.O, Box 100360, Anchorage, Alaska 99510 4, Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. I 6 . Lease Designation and Serial No. see attached 7. Permit No. see attached, 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other '~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list cfi^producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion-_- to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 019" 5 AlaSKa 0H & Gas Cons. Gommission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Approved by ~~ ~~'~ Form 10-403 Rev. 7-1-80 Tit,e. Kuparuk Operations Coordinator Date 9/18/85 etu~ / ' By Order of l_,-~. COMMISSIONER the Commission Date__ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, Ir~ Post Offic( ~.~:)x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO:5332A **CONTINUATION ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRA/qSMITTED RECEIPT AND SEQUENCE OF 2G-9 f PBU 2G-9~- PBU 2G- 11'"' PBU 2G-16 ~'~ SB~P 2h-l-- PBU 2h- 1--- PBU 2U'l "' ' C ' 2U-1 -~ END 2W-7 -" 'C' 2W-7 / 'C ' 2W-7/~j- 'C' 2X-ll'_J pBu 2X-11 / 'C' 2X-11/ 'C' 3C-5 / BhP 3 C- 7/ BHP 3C-8 / BHP 3C-9/-- BHP 3C-10 ,/BHP HER~.%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURI~ ONE SIGNED COPY OF THIS TRANShITTAL. EVENTS FROM WELL SERVICE ~{EPOKTS/PRESSUR~ DATA SAND PBU 'C' SAND PBU SAND PBU SAND PBU SAND PSU & MISC. SAND PBU SAND PBU & MISC. & MISC. & MISC. & MISC. & MISC. 08-22-85 08-21-85 08-19-85 08-19-85 08-25-85 08-24-85 08-23-85 08-24-85 08-17-85 08-23-85 08-22-85 08-24-85 0~-25-85 08-26-85 08-29-85 08-30-85 08-31-85 08-09-85 08-10-85 KU PARUK WELL 3C-12/ 3C-10~ 3C-9 ~ 2Z-16-- 2Z-15 '- 2Z-14,- 2Z-13" 2X-4~ 2X-4" -2U_l-~ 2A-13~ 1R-10 -~ 1R-9 -'~ PRESSURE STATIC 'A' SAND STATIC 'A' SAND STATIC 'A' SAND STATIC STATIC STATIC PBU PBU STATIC STATIC STATIC REPORT ENVELOPE FACES 07-24-85 08-10-85 08-09-85 07-21-85 'A' SAND 07-17-85 07-20-85 'A' sAND 07-17-85 08-12-85 08-13-85 08-24-85 08-25-85 'A' SAND 08-15-85 'A' SAND 0~-14-85 CAMCO OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO C~ICO RECEIPT ACKNOWLEDGED: sPAE* B. CURRIER CHEVRON* ~ & M* DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON MOBIL*' PHILLIPS OIL* NSK CLERK J. RAT~MELL* f'.~ · ~.--';.,. ..... . .,-.~.,%~ - DATE: 4ta~k.'-3 ~'" ~'~' ~' ~ -:. - ~. -~ bi,,% STATE OF ~ASKA* ":: .... ,..'" ~":"~'~-"~. SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary o! AllanlicRichfieldCompany ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 13, 1985 Mr. C. V. Chatterton commi ssi oner state of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2Z-16 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2Z-16. I have not yet received the Well History. But when I do, I will forward a copy to you. Also, tubing details will be submitted when the well has been completed. If you have any questions, please call me at 263-4944. sincerely, Gruber Associate Engineer JG/tw GRUlO/L118 Enclosures RECEIVED ! 6 198§ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alasks, inc. is a Subsidiary of AtlanticRichlieldC°mpany STATE OF ALASKA ALASKA L. ~ AND GAS CONSERVATION CC vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED r~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-109 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21:~62, 4. Location of well at surface~ 9. Unit or Lease Name 1291' FSL, 327' FEL, Sec.11, TllN, RgE, UN ILC~ATIO_NSI Kuparuk River Unit At Top Producing Interval 1 VERIFIj~,cr' 1 10. Well Number 1561' FNL, 1274' FWL, Sec.ll, TllN, RgE, UM Surf. r/ i 2z-16 At Total Depth B.H._L1 11. Field and Pool 1236' FNL, 970' FWL, Sec.11, T11N, RgE, UM -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBI ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/02/85 06/07/85 06/10/85I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8150'MD,6247'TVD 8018'MD,6153'TVD YES ~X NO [] N/A feet MD} 1500' (approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Ca 1, G)' ro 23. CASING, LINER AND CEMENTING RECORD SE'ri-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 255 sx PF "C" 9-5/8" 36.0# J-55 Surf 4081' 12-1/4" 1100 sx CS Ill & 450 s~ CS II 7" 26.0# J-55 Surf 8102' 8-1/2" 435 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED tU'"l s 1985 Alaska 0il & Gas Cons. Commission Form 10407 TEMP/WC83 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , , .... \:-:~-.i-., .~.~ .: .t,,~.',._.:,. · .-.. :..: .. ..:..' _:,~.~;,: . .. 29. -"- _30 ........ " ,. ..~,.~ .:-"':'~' 'i:.,..~': '¢;':"'~:::'~': ',- '~ GEOEOGIOM/~RKERS '~ -:~ ::'!':: -"::?'~" ~:~''''- ' : :~-,: :~!'-"'>~::": ..... .-'4:.:. .-;:' :.~:.::: ;:':! ',. :' :: :i~.i ~..';',~. ',!.:':.:;... ;.,-.':F0~.M~Ti0N?i_E~;~S,,. .- ' .;' ....... :~ ' ~-:'~" ~:, : · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper 5and 7510~ 5787~ N/A , Base Upper Sand 7616' 5865' Top Lower Sand . 7788' 5989' Base Lower Sand 7966' 6116' · . 3~. LIST OF ATTACHMENTS __. GYroscopic Survey (2 copies): 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed i~I ~ ~ Title Associate Engineer Date ~'/~-~' INSTRUCTIONS General' This form is designed for submitting.a complete and correct well completion report and Icg on all types of lands and leases in Alaska, - Item 1' classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval .reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Me[hod 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". ARCO Oil and Gas Company Well History - Initial Report - Daily Inst~'uctione: Prepare and submit the "lnlUal 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 ]County. parish or borough I State Alaska I North Slope Borough I Lease or Unit I ADL 25646 I Title J Drill Field Kuparuk River Auth. or W.O. no. AFE 603481 Nabors 26E Alaska JWell no. 2Z-16 AP1 50-029-21363 Operator [ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IData [Hour {Prior stel-s Spudded 6/2/85 0001 hrs. Date and depth as of 8:00 a.m. 6/03/85 6/04/85 6/05/85 6/06/85 6/07/85 Complete record for each day reported 56.24% If e W.O. 16" @ 103' 3000', (2897'), Drlg Wt. 9.1, PV 21, YP 31, PH 9, WL 11, Sol 5 Accept ri~ @ 1700 hrs, 6/1/85. NU diverter sys. Spud well @ 0001 hfs, 6/2/85. Drl & surv 12¼" hole to 3000'. 430', .5°, S50.2W, 430.0 TVD, .5 VS, 1.25S, 1.4W 965', 14.6°, N57.aW, 959.7 TVD, 63.5 VS, 29.1N, 56.9W 1333', 25.4°, N56.8W, 1305.0 TVD, 189.1VS, 98.4N, 161.7W 1713', 36.7°, N55.8W, 1631.3 TVD, 382.6 VS, 203.7N, 324.0W 2026', 44°, N60.8W, 1868.1TVD, 586.7 VS, 307.9N, 499.7W 2554', 46°, N59.aW, 2241.4 TVD, 959.2 VS, 492.9N, ~7~-.OW 9-5/8" @ 4081' 4100', (1100'), Cmt 9-5/8" Wt. 9.9, PV 18, YP 10, PH 8.5, WL 8, Sol 10 Drl 12¼" hole f/3000'-4100', short trip, C&C, POH. Rn 99 Jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4081'. M&P 1100 sx CS III. 3027', 46.3°, N57.aw, 2569.1TVD, 1300 VS, 669.6N, 1115.8W 3494', 45.4°, N56.8W, 2894.4 TVD, 1635 VS, 850.6N, 1397.7W 4030', 44.5°, N55.8W, 3273.7 TVD, 2013 VS, 1060.7N, 1712.8W 9-5/8" @ 4081' 4500', (400'), Navi-Drl Wt. 9.0, PV 7, YP 9, PH 10.5, WL 18.4, Sol 4 M&P 450 sx CS II @ 15.3 ppg. Displ w/mud & bump plug. CIP @ 0715 hfs, 6/4/85. ND diverter, NU csg spool & BOPE; tst same. PU BHA, RIH, tag @ 3988', tst csg to 1500 psi. Drl to 4110'. Tst formation to 12.5 ppg EMW. Drl &Navi Drl to 4500'. 9-5/8" @ 4081' 6960', (2460'), Navi-Drl Wt. 9.5+, PV 16, YP 11, PH 9.5, WL 6.4, Sol 8 Navi-Drl & surv 8½" hole to 6960'. 4571', 43.5°, N55.aw, 3662.9, 2389.5, 1271.9N, 2023.6W 5292', 44.0°, N57.aw, 4176.8, 2895.0, 1554.4N, 2442.9W 5760', 45.0°, N52.aw, 4510.6, 3222.9, 1741.1N, 2712.5W 6103', 48.0°, N53.8W, 4746.7, 3471.3, 1889.7N, 2912.0W 6634', 47.1e, N55.aw, 5113.1, 3855.2, 2114.4N, 3223.7W 9-5/8" @ 4081' 7850', (890'), Drlg Wt. 9.5, PV 11, YP 6, PH 9.5, WL 5.6, Sol 9 Navi-Drl & surv 8½" hole to 7850'. 7108', 40.6°, N57.aw, 5454.7, 4183.4, 2294.1N, 3498.3W The above is correct For form preparation and distribu~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. I Date l~itle 7/24/85~ Drilling Superintendent i< E i V kC cCE[ VED AR3B-459-1 -D ally I ' { m consecutively iPige no. ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: 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 Ut 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. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ~Lease er Unit Well no. Kuparuk River I ADL 25646 2Z-16 Auth. or W.O. no. ~Title AFE 603481 I Drill Nabors 26E API 50-029-21363 Operator A.R.Co. W.I. rrotal number of wells (active or inactive) on this~ Date 56 · 24Z Icost center prior to plugging and I ARCO Alaska, Inc. [abandonment of Ihis well Spudded or W.O. begun IH°ur I Prior status if a W.O. Spudded 6/2/85 ! 0001 hrs. I Date and depth Complete record for each day reported as of 8:00 a.m. 7" @ 8101' 8150', (300'), RR Wt. 10.0, PV 16, YP 8, PH 9.5, WL 6.0, Sol 12 Drl f/7850'-8150', CBU, short trip to 4113', C&C, POH. RU & log DIL/8~/FDC/CNL/CAL; could not pass 7798'. GIH, wsh & rm 7610'-8030', C&C, POH. Log DIL/~I~/GR/FDC/CNL/CAL f/8140'- 4084'. GIH, C&C, 15 std short trip, POH. RU & rn 198 its, 7", 26(~, J-55 BTC w/FS @ 810~', FC @ 801~'. Cmt w/435 C1 "G" w/3% KC1, 0.7% D-19, 0.3% D-31 & 0.1% D-6 + 1 gal/100 sx HR-12. Displ w/9.5 NaC1/NaBr. Bump plug w/3000 psi. Flts did not Set slips. ND BOPE. NU 6/08/85 thru 6/10/85 hold. CIP @ 1915 hrs, 6/9/85. WOC. & tst tree. RR @ 0330 hrs, 6/10/85. Old TD New TD 8150' (6/7/85) Released rig Date 0330 hrs. 6/10/85 Classifications (oil, gas, etc.) Oil ' ,/t,,,.,~ c,,,. PB Depth Kind of rig ~0~ Type complelion (single. dual, etc.) StaBle 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 Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Ellecfive date corrected The above is correct 7/24/85 Drilling Superintendent For form preparation and distribu~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iage no. Dlvlflon of AtlanllcRIchfleldCompany ARCO Alaska, in¢ Post Office aox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE:07-16-85 TRANSMITTAL NO:5250 RETURN TO:. TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O, BOX ~00360 ' ~A ANCHORAGE AK 99510 HEREWITH ARE THE FOLLOWING ITEMS CKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE FINAL PRINTS/SCHL (ONE * OF EACH) 2V-16 5" DIL/SFL-GR 06-03-85 RUN #1 2995-7206 2" DIL/SFL-GR 06-03-85 RUN #1 2995-7206 5" DEN/NEU-GR PORO 06-03-85 RUN 91 2995-7181 2" DEN/NEU-GR PORO 06-03-85 RUN #1 2995-7181 5" DEN/NEU-GR RAW 06-03-85 RUN #1 2995-7181 2" DEN/NEU-GR RAW 06-03-85 RUN #1 2995-7181 CYBERLOOK 06-03-85 RUN #1 6300-7133 2Z-16 5" DIL/SFL-GR 06-08-85 RUN #1 4084-8132 2" DIL/SFL-GR 06-08-85 RUN #1 4084-8132 5" DEN/NEU-GR PORO 06-08-85 RUN #1 4084-8106 2" DEN/NEU-GR PORO 06-08-85 RUN %1 4084-8106 5" DEN/NEU-GR RAW 06-08-85 RUN #1 4084-8106 2" DEN/NEU-GR RAW 06-08-85 RUN #1 4084-8106 CYBERLOOK 06-08-85 RUN #1 7290-8083 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M*BL DISTRIBUTION: DRILLIN*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*EL J. RATHMELL*BL DATE: Alas~ Oil& STATE OF ALA~KA~BL SOHIO ......... UNION K.TULIN/VAULT*FILMS ARCO Alaska. tnc. ~s ,3 SuDs,diary of At;anlicRichheldCompany ,~' STATE OF ALASKA ALASKA (._-'AND GAS CONSERVATION CO,7¢11SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ X Workover operation 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-109 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21363 4. Location of Well atsurface 1291' FSL, 327' FEL, Sec.ll, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB 6. Lease Designation and Serial No. APL 25646 ALK 2577 For the Month of June ,19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2Z-16 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0001 hrs, 6/2/85· Drld 12-1/4" hole to 4100'. Ran, cmtd, & tstd csg. Drld 8-1/2" hole to 8150'TD (6/7/85). Ran logs. Ran, cmtd, & tstd 7" csg. 8016'. Secured well & RR ~ 0330 hfs, 6/10/85. 9-5/8" PBTD = 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, U-40, weld conductor set ~ 103' Crntd w/255 sx PF "C" , · · · 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe (~ 4081'. Cmtd w/1100 sx CS III 7" 26 O#/ft, J-55, BTC csg w/shoe ~ 8102' Cmtd w/435 sx Class G , · · · & 450 sx CS II. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/FDC/CNL/GR/Cal f/8140' - 4084' 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Associ ate Engineer DATE 7-/0-(~' .......... NOTE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. c~.m ~n~nm TEMP/MR78 Submit in duplicate ARCO A, Inc. Post OHice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE- 06-2 7-8 5 TRANSHITTAL NO: 5235 URN TO' ARCO ALASKA, INC. KUPARUK OPE ~.TIONS R,'.~O:~DS CLERK ATO-!llSB P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING :ED HER.D..'~ITH ARE '-~"E.~ FOLLOWING I~E~.~S. AND RETURN 'ONE SIGNED COPv. OF THIS TAPES PLUS LIST~'~ ~ (ONE COPv OF EACH) PLEASE ACKNOWLEDGE REF ~70482 REF #70506 *REVISED* - . DiSTRIBUTiON: ~'7. PA S:."S 2 . '"',r' ~ I.L r p,~'_ O~ J. ?C: T ![M E L L DA~E - TATE"OF' ALASKA · U,.'.]ZON K. TULiN/VAULT OPEN [iOLE LIS SCiILUMBERGER 3C-i2,~ 06-!6-85 RUN ~! 3756. 0-7598. 0 REF ~,70547 3B-8~ 06-02-85 RUN ~1 3925.5-8516.0. Rr..:F ~70495 3B-7~ 05-24-85 RUN #i 3268. 0-7310. 5 REF #70468 3!~-9~ 06-10-85 RUN ~1 3988.0-8415.0 REF #70526 ..,.~-5--.,, 05-1° 85 RUN ~1 3aa7 5-81zt8 0 REF ~,70417 2Z-16~ 06-08-85 RUN #1 4062.5-8163.5 REF ,~70525 2V-16-,.. 06-03-85 RUN #! 2973.0-7168.0 REF ~70496 2V-15-...~ 05-24-85 RUN #2 2573.0-6544.5 REF #70470 2V-14 ~ 05-16-85 RUN #1 3047.0-7086.5 REF %70426 2V-13 --~ 05-07-85 . RUN ~1 3536.5-8710.5 REF ~70409 LR-8~ 06-14-85 RUN #1 4040. 5-8576.5 REP' i~70546 ]R-6---. 05-14-85 RUN ~,! 4623.5-9332.5 REF #70422 JQ-!5~ 05-12-85 RUN #1 4390.5-8730.0 P.E[" #70415 iQ-!'' ~ 05-21-85 RUN ~- ~,1 4371.0-9027.5 REF #70447 iQ-13x...~ 05-30-$5 RUN ~1 3~79.0-7772.5 LQ-4 ~ 03-18-85 RUN ~.1 4570.0-9471.0 ARCO Alaska, Inc. Post Office Bo,, -t00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2Z-16 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2Z-16. I have not yet received a copy of the well history. When I do, I will forward a copy to you. Also, the bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU10/L32 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED Alaska Oil & Gas Cons. Conrim/ssion Anchorage ~-~ STATE OF ALASKA .,--. 0 I]I GINA L ALASKA(,..AND GAS CONSERVATION CO AISSION WELL COMPLETION OR RECOMPLETION I EPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED r~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-109 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21363 4. Location of well at surface 9. Unit or Lease Name 1291' FSL, 327' FEL, Sec.ll, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2Z-16 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 109' RKB ADL 25646 ALK 2577 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/02/85 06/07/85 06/10/85 N/A feet MS L 1 17. Total Depth (M D+TV D) 8150' MD 18. Plug Back Depth (MD+TVD) 8018' MD YES19. Directional Survey[] NO I-~X I20' Depth where sSsV setN/A feet MD I21' Thickness °f Permafr°st1500' (app fox ) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/Ca ] 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 255 sx PF "C" 9-5/8" 36.0# J~55 Surf 4081' 12-1/4" 1100 sx CS III & 450 s: CS II .. 7" 26.0# J-55 Surf 8102' 8-1/2" 435 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A -, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A .. : ,, 27. N/A PRODUCTION TEST Date First Production Method of Operation IFIowing, gas lift, etc.} Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I~iow Tubing Casing Pressure CALCULATED=~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alaska 0il & Gas Cons. Commission Anch0ra!~e Form 10~407 JNM2/WC54 Submit in duplicate Rev. 7-1~0 CONTINUED ON REVERSE SIDE Gl MARKERS '~ :.; ;. if -;.~( . ~F'?- 5 ~::~".'.,_.~",~,.;'~"'% ;.. :-: .',-:: :- :FOAMATI'0N'~'E's.Ts' .g~,_~,t¥. ~:-,' -. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH. GOR, and time of each phase'. · 1o be aubm'i~:'l:ed w~ ~n ~yro i~ run. N/^ ' .~. · · : . · · . . 31. lIST OF ~TTACHMENTS ltlon _~. ..... 32. ! hereby certify that the foregoin§ is true and correct to the best of my knowledge · . INSTRUCTIONS General' This form is designed ·for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection; salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate Which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ,' Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". SUB-SURFACE DIRECTIONAL SURVEY [~UIDANCE [~]ONTINUOUS ~"IOOL Company Well Name . Field/Location ATLANTIC RICHFIELD COMPANY · 2Z-16~ (1291,' F,SL. 327' ~EL. Sll. TllN. RgF.. ~M KUP~RUK. NORTH SLOPE. AT. ARWA . Job Reference No. 70690 L0~aed LESNIE RECEIVED .~,u,., i ~ !985 Alaska Oil & Gast;on~, '~ ~ Commission Oats 02-AUG- 1985 Computed Ely: WILKIE GC? DI~ECTIONAb SURVEY CUSTOMER b~STIN~ FOR ARCO 'ALASKA, INC, KLIPARUK NORTH SLOPE,ADASKA SURVEY DATE: 7-1-85 ENGINEERI LESNIE TOOL Lf]CATT{~N: TANGFNT[A[,- averaqed dev~ation and azimuth ,, INTE~POb~TION: VERTICAL SECTION: HORTZ. DI~T. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 56 ARCh ~LASKA, TN(:', 2Z-,I 6 NORTH SbOPE;, AI',ASK A TRUE SUB-SER 'EaSI. INED VERTICAL VE~TICRb DEVIATION AZIMUTH DEPT~! DEPTH DEPTH DEG'MIN DFG 0.00 ~0o.00 400,00 500,00 600,00 700.o0 ~00 oO 900~00 0 O0 -109,00 0 0 100 O0 -g,o0 0 12 200 OO 91,00 0 20 300 00 399 99 499 gq 599 90 699 43 7O8 53 8q6 76 COMPOTATInN DALE: 30-JOb-85 PAGE DATE OF 8URVE¥I KEbbY BUSHING EbEYA~ONI ENGINEERI bESNZE .. INTERPOLATED VALUES FOR EVEN 100 fEET or MEASURED D~PTH ,,~'~ VERTTCAh DOGbEG RECTANGUbAR COORDINATES HORZ'~i DEPARTURE SECTION ~EVERITY NORTH/SOUTH EAST/WES~ DI$~'~ AZIRUTH FEET DEG/IO0 FEET FEET FZ~T,', D~G MX.N ,j,, , N 0 0 g 0.00 $ 41 I F -0,32 N 7b 30 E -0,67 191,00 0 26 $ R4 1.4 E -t,24 290.99 0 21 S 69 13 E '1,94 390 99 0 21 N 17 41 W -2,19 490:90 4 13 N 49 10 W 1,45 590:43 6 38 ~ 58 12 W 11.05 68~ 53 9 14 N 62 36 W 24,10 787.76 12 13 N 60 25 W 42,88 lO00.nO 993 85 084,85 15 17 1100 O0 10~9 63 980,63 18 16 1~00~00 11~3 86 1074,86 ~0 34 1300 O0 1276 30 1167,39 24 10 1400~00 1366 77 1257,77 26 14 1500 O0 1455.24 1346.24 ~9 32 1600'00 1541.10 1432,1.0 32 1700~00 1.623,70 1514,78 36. IRO0,O0 1703,23 1594,23 38 33 1900,00 1779,6~ 1670,62 41 30 2000.00 1853,34 1744,34 43 15 2100.00 19~5.66 1816.66 44 13 2200.00 1996,67 1,~7.62 45 1 2300.00 2067..23 195,.23 45 12 2400.00 2137.66 2028 66 45 16 2~00.00 2207,7~ 2098:78 45 37 2600.00 7277.71 2~6~,71 45 30 2700,00 2347.75 2238,75 45 35 2BO0,O0 2417,81 230~,R1 45 27 2900.00 ~487.86 2378,~6 45 41 N 58 0 W 66,77 "57 6 W 95,46 N 56 44 W 128,9i N 57 22 W 166,77 ~ 57 2~ W 209,53 ~ 58 6 W 256.12 N 58 1] .W 307,33 N 56 42 W ]63.52 N 57 14 W 424,24 N 60 27 W 488,68 N 61 27 W 556,00 N 60 lq W 624,84 N 59 47 W 695,18 N 59 34 W 765.87 N 59 26 W 836,76 M ~9 1 W 907,98 ~ 5B 50 W 979.41 N 58 37 W 1050,72 N 58 24 W 1~2~,04 N 57 46 W 1193,37 N 57 8 W 1264.92 N 56 24 W 1336.53 ~I 56 26 W 1407.79 ~ 56 34 W 1478.92 w 56 29 W 1549,84 P{ 56 q W 1620,72 N 55 57 w 1691.44 ~ Kb 4 w 1762.16 ~ 5b li W 1832.7! ~.~ 5~ 16 w 1902.96 3oO0.nO 7557.71 244~.71 45 40 3100.00 26~7.50 2~1R,50 45 35 3200.00 ?b97,b6 2588.66 45 23 3300o00 2767,96 265~.~6 45 3400.00 2838,46 2729,46 45 3 3500.00 ~909,00 2RO0.O0 45 5 3600,00 2979,69 2R70,69 45 3700.00 30~0.30 2041.39 44 5R 3800.00 t191.25 301~.25 44 3qo0,o0 3102.42 3083.42 44 20 0.00 21 3fl 09 17 85 56 33 04 68, 2 55 3 44 2 43 2 3 59 3 93 3 2 94 1 31 2 O? 0 17 0 4O 0 4O 0 39 0 60 0 21 0 18 0 38 0 85 0 56 0 .23 0 39 0 27 0 54 0 25 0 38 0 21 0 44 0,00 N 35 8 ,32 $ 0538 0528 2 10 N 7 71N 14 23 N 23 03 M 0 O0 E g19 E I28 g 2 28 E 0 35W 8 15 W 19 72 W 36 16 W 35,38 56 50,78 ~ 80 89, 140 112, ~ 176 137 66 , 216 164,36 259 ,73 157 ,10 261,52 ~ 412 362 398 434 47O 507 544 582 619 35 ~ 53 67 N 59 38 N 654 40 N 715 87 N 777 81 N 838 83 N 899 10 N 960 82 N 1020 109,00 FT 46 ~ 58' 5~ 52 86 ~' 65 ~ 12 ,93 64 6 ,79 ~ 5? 35 06 ~ ,56 16 ~ 57 27 59 36 04 ~6 , 94 , 39 2O W 556 65 W 625 6t W 695 75 W 766 93 W 637 19 W 906 39 W 960 41W 105t 26 W 1122 84 W i194 2 n 58 5 W N 58 25 W 3 N 56 34 w 43 N 58 40 41 N 58 45 .. 70 N 58 47 W N 56 47 W 6 h 58 47 W 92 N 58 46 W 28 N 55 44 W 658 22 N 1081 23 W 1265 82 N 56 40 W 697 56 N 1141 07 W 1337 40 N 58 33 k 736 776 815 933 972 1011 97 N 1200 23 N 1259 30 N 1318 62 n {495 91 N 1553 96 N ~6~2 I 94 W 24 W 176 84 W 1833 24 W 1903 61 56 27 21 58 N t6 ~ 30 N 57 56 W 52 N 57 53 W 2~-~6 KtlPAR~!K T~UF SUB-SEA ' . ~ COUPSR EASUHFD V~RTICAL VERTTCAb DEVIATION AZIMUTH DEPTH D~PTH DEPTH ...PEG MIN DEG M~N COMPUTATION DATE; 30-JU[.,-85 KEbbY BUSHING EbEVR~ONi ENGINEERI' INTERPOLATED VALUES FOR EVEN ~00 FEET OF MEASURED DEPTH ,, ' .~; DEPARTURE VERTTCAb DOGbEG RECTANGUbRR COORDINATES HORZ SECTION SEVERITY NORTH/SOUTH E~ST/WE8~ 4000,00 3263 95 31 54,95 44 12 4100,00 3336:76 3226,76 43 55 4~00,00 3407:50 3~9R,50 44'18 4300,00 ~479 14 3370,14 44 4400.00 3551.11 3442.11 43 48 4500,00 3623,46 3514,46 43 27 4600,00 369b,16 3587,16 43 15 4700,00 3768,95 3659,95 43 49 4800,00 3840,11 3731,11 45 4~00,00 3910,68 3~01,68 45 4 5000.00 3981 45 3~7~ 45 44 50 5100.00 4052 47 3043 47 44 38 5~00.00 4123 87 4014 87 44 5300.00 4105 5400.00 4268 5500.00 4339 56.00.00 4409 5700.00 4479 5800.00 .4550 5900.00 4622 78 4086 78 43 40 tO 4159 10 d3 50 3n 4~30 ~8 45 15 37 4~00 37 45 30 73 4370,73 45 6 67 4441,67 44 23 41. 4513,41 44 6 N 56 1~ W 1972.85 ~ 56 22 W 2042,43 56 11 w 2i12 1o N 56 18 w 2181:88 se 35 w 2251. 30 ~ 57 0 w 2320 34 N 57 4 W 2388 99 N 57 7 w 2457 55 ~ 57 3 W 2527 81 N 57 16 W 2598 66 N 57 23 W 2669 30 N 57 25 W 2739 ~) 57 28 W 2809 ~ 57 35 W 2879 N 57 27 W 2948 ~ 54 37 W 3018 ~ ~3 34 w 3089 N 53 54 W 3160 ~ 54 I w 3231 ~ 53 55 W 3300 68 69 17 22 34 68 65 06 66 0 23 0 94 0 20 0 48 0 30 0 43 0 40 I 78 0 43 0 16 0 32 0 24 0 29 0 5i I 22 0 0 4~ 0 46 I O9 PAGE 2 109' O0 FT , , 1089 30 1728:30 2042 N' 46 '1786,25 'N 29 72 1844, 5 N 38 ,242 ~ 1959, 1280 2017, 44 57 36 13'17 44 2075,11 O0 N 59 2134,06 25 5734 1394 02 N 2193,64 W 11 N 57 33 '50776 237143 28i0 57 '545 06 ~ ~ 2430 06 16~0 ~ ~ 254675 30'" ~ ST 1 57 N 27 8 1746787 55 N 27'5767 W 32310036 N 1 6000.00 4692 88 4583.~8 46 45 6100.00 4760:27 4651.,27 47 43 6200,00 4828.12 4716,$2 46 4~ 6300.00 4897.40 4788,40 45 30 6400.o0 4967 91 4858.~ 44 53 6500.00 5039:16 4030.16 44 37 6600.00 5109,01 5000 O1 46 36 6700.00 5178.14 5060:14 45 16 6800.00 K250,01 51.41'01 42 57 6900.0o 5323.93 5214.93 41 47 ~ 54 25 W 337i,54 ~ 54 16 W 3445.37 ~ '4 2~ w 3518,77 N 54 21 W 3590.84 N 54 35 W 3661.70 N 54 39 W 3731,83 ~ 55 2 W 3803.34 ~' 55 54 w 3875.58 N 55 59 W 3945.10 ~ 56 27 w 4012.44 316 0 97 I 43 1 O2 0 64 ! 56 1 39 2 4'/ 1 46 1 0'/ 1829 02 N 2831 56 W 3314 76 N ~? 8. W 1872 15 N 289 56 W 34 55 N 7 5 W 191499 23 W 3516 93 N 57 1 '" 1956 98 , 3010 85 W 359 0 1998 20]8 2080 2120 2159 2197 N2952 19 77 ~ 306 312~ 13 ~ 31~ 95 324~ 89 330 6 18 3803 80 ~ 3875 39 3945 36 N 4012 6 N 56 58 56 53 ~ 56 Ii ! 0 N 56 W 7000.00 5399.10 5290.!0 40 46 7100.00 5475.10 5366,10 40 17 7200.00 5551.60 544~.60 40 7300.00 55~7.86 5518.66 40 740n.o0 57o4.0n 5~95.00 40 43 7~0o.oo 5779.51 5670.51 4113 7600.~0 5853.70 5744.70 7700.00 ~9~6,1~ 5R17,12 43 7RO0,OO 59~.11 5~8O,ll 44 1 7coO,nO ~o69,~9 5°60,49 44 50 H 56 49 W 4078,40 N 57 3 W 4143.38 N 57 14 W 4207,79 ~ 54 4] W 4272.46 " 50 0 W 4337.11 N 45 2 W 440~,85 ~ 44 4 W 4467.35 ~ 43 56 W 4534.?0 ~'a3 2! W 460~,37 ~!d2 57 W 4670,52 0 78 0 71 I O0 2 35 3 30 2 55 1 36 0 56 0 79 1 06 2233,6~ ~ 3412,45 ~ 4078,45 N 5647 W 2303 ~ ~ 352i.0' ~ 4207.84 48 4272, 47 2339 3574.85 52 ]674,69 44~ 5624 2521 3769.42 453475 56 56 26222571:]] ~ 3817'32 3865.23 ~467'046028252 t~AGE A~Cn AL, ASKA, [NC, PATE Or SURVEY! KIIPAR[IK , , [~ERPObATED VAbUE;G FOR EVE~~ l, O0 FEET OF MEA$URED DEPTH ,,,, ~RUF SUR-SE~, ~' ' ' COURSF VERT~CAb DOGbEG RECTANGUbAR COORD'~NATES EAS[~RFD V~RTICA[, VERTTCAb:DEVIATION AZI'~LITH SECTIO~t SEVERfTY NORTH/SOUTH EAST/WEST PlS~e',:'~,,," AZIMUTH DEPTH DFPTH DEPTH ,DEG MIN D~G M~N F~ET DEG/tO0 FEET FEET ~E~, WIN 8100:00 6211:46 6]0~,46 44 46 N 41 56 W 48~,95 0,00 2726,81 N 3959,68 8~50.P0 6246,96 613T,96" 44 46 N 41 56 W 4841,03 0,00. 2753~01 N 3993~22 W 484~e0~. N 5520 PAGE 4 2%-16 KUPARI~K NORTft SLC}PE,ALASKA ENGINEER $09,00 rT INTERPOLATgn VALUES FOR gVgN lO00 FEET OF MEASURED OEPT , TR{.J~ SUP-SEA COURS£ VERTTCAL DOGbEG RECTANGUbAR COORDINATES HORI~,:I DEPARTUR~ IE;A$IIR~.'D V~RTICAL VEPTTCAL DEVTATIDN A~Z~UT'H SECTION SEVERITY NORTH/SOUTH ERST/WEST DIST,,' AZZMUTH ~gPTP D~PTH D~PTH DEG MTN I)~G I~IN. FE£T DEG/IO0 FEET FEET . F~ , DEG MXN 0.O0 1000,00 903 2000,00 1853 3000,O0 4000,00 3263 5000,no 6000,00 4602 7000,~0 5399 8o00 O0 6140 8150:00 6246 0 O0 -10q,00 0 ~5 ~84,~5 i5 17 34 1744,34 43 15 71 2448,7! 45 40 95 3~54,95 44 45 3872.45 44 50 88 4583,88 46 45 10 5290.10 40 46 47 b03~.47 44 46 96 6137.O6 44 46 N 0 0 ~ 0,00 ~ 58 0 W 66,77 N 61 27 W 556,00 ~ 57 8 W 1~64,02 ~! 56 18 W 19'/~ 85 N 57 23 W 2669 ~0 N 54 25 w 3371' 54 ~ 5b 4~ ~ 4078 40 ~{ 41 56 ~ 4738 79 N 41 56 W 4841 03 0,00 2,55 ! 3! 0~85 0 23 3 ~6 0 On 0 O0 0 O0 N 35 293 1432 1829 2233 2674 2753 0 38 N 56 95 N 472 22 ~ 1081 70 N 1670 17 N 2253 02 M 2832 60 ~ 3412 42 N 3912 O! N 3983 O0 E 0 66 ,W 66 20 W 556 23 W 1265 4! VI !9'73 10 VI 2669 56 VI 33'71 45 VI 40'/8 W 4842 CONPUTAT[ON DATE= 30-dUb-g5 ARCO A. bASKA, TNC 'DATE OF SURVE¥I 7-1-85 2Z-lb ' ' KELbY BUSHZNG EbEVATZON1 K[IPARVlK NORTH SLOPE,ALASKA ENGTNEER{ bESNXE INTERPOLATED VAI.,U~S FOR EVEN 100 FEET OF SUB-SEA DEPTH ~" '~ T~Ug SU~-SEA ' COUR$~ VERTTCA~ DOGLEG IEASURFD V~R?I~AL VEST'CAb DEVTATION AZIMUTH SECTION SEVERITY DEPTH DKP?H DEPTH DEG..'M~N DKG ~N FEET PEG/lO0 PAGE 5 109,00 FT NORTH/SOUTH EA$'PtWgST D,.{_.~_Te;.,,::i:/:,:: XHUTH FEET FEET f't;~T/ ~,,,:, DEG MXN 0,00 '9 00 109:00 ~Og oo 300iol 40g O1 509 O1 609~13 709,64 ~10.61 0.0o 1o9,0o 209 O0 309 O0 409 O0 509 O0 609 O0 709 O0 809 O0 91~,52 909 O0 101~,~1 1009 6,02 1209 1335,~9 1309 1447,]7 1409 1562.33 1509 1681 76 1609 1807~39 1709 1939,50 1809 -1. On 00' 0 0 -100~00 0'14 0.00 0 12 100,00 200,00 ]0o O0 400 O0 500 O0 60O O0 700 O0 0,22 0 26 0 20 0 34 4 31 b 48 9 37 RO0,O0 12 35 O0 gO0,O0 15 41 O0 1000,00 18 54 O0 1100,00 21 21 O0 1700,00 25 7 O~ 1~00 O0 ~7 30 O0 1400 O0 31 ~ On 1~00 O0 35 29 oo oo oo oo 2076.81 1909 O0 1800,nO 43 51 2217,53 2009 O0 lOOO,O0 45 2 235g ]1 2109 O0 2000,00 45 12 2501~74 2209 O0 2100,00 45 37 2644 63 ~309 O0 2200.00 45 278~45 2~09 O0 2~00,00 45 27 2030.~8 2509 O0 2~00,00 45 43 3073.52 2609 O0 2~00.00 45 43 3716,14 2709,00 2600,00 45 21 3358.30 2809,00 2700,00 45 3800.01 2909,00 2"00.00 45 5 3641.47 t009.00 2000.00 44 59 3787.7b t109,00 3000.00 44 46 3923 ?1 3209,00 3100.00 44 25 4062:~2 ]309.00 3~00,00 44 4 4~0~.10 3409.00 3]00.00 44 1R 4341.58 ]509.00 3400.00 44 4480,08 .~b09,00 3~00.00 43 31 4~17,~1 ~709'0o 3600,00 43 4756,00 ]809,00 3700,00 44 4'7 N 0 0 E 0,00 N 43 45 E 0,00 $ 46 42 E -0,36 N 77 32 E -0,71 $ 82 54 E -1.30 $ 70 ~ E '1,99 N 27 0 W -2,13 N ~0 8 W 2,16 N 58 46 W 1~,19 N 62 42 W 26,04 N 60 I W N 57 49 W N 56 56 W N 56 56 W N 57 23 W ~' 57 40 W N 58 40 W. 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KEbbY BUSHZNG Eb~VA~ONI 109,00 ENGINBER l INTERPOLATED VA[.UE~ FOR EVEN 1.()0 FEET OF' SUB-SEA DEPTH " ~EC~I~N SEVERZT) NORTH/SOUTH ERST/WES~ DIS~,';:'",AZIMU~H 4897.03 3909 00 3~00,00 45 4 5038,~4 4009 O0 3900.00 44 47 1o9 oo 4000.00 ,s 531n.31 4209 00 4100,00 43 44 5457 08 43O9 O0 470~,00 44 3q 5599:47 4409 O0 430~.00 45 30 5741.42 4509 O0 4400 O0 44 55 5~81 3b 4609 O0 450d:00 44 0 6023172 4709 O0 4600,00 47 20 617~.03 4~09 O0 4700,00 47 3 6~16 56 4909 O0 4800,00 45 26 6457:79 5009:00 4900,00 44 2q 659q'99 5109' OO 5000.00 46 36 6743.44 5209 O0 5~00.00 44 ~ 687~,94 K309 oO 5~00.00 42 0 701~:o6 S409 O0 5)00 80 40 41. 714 35 55n9 O0 5400~ 0 40 3 7275.32 5609 O0 5500.00 40 1~ 7406.60 5709 O0 5600,00 aO 46 7539.~6 5809.00 5700.00 41 52 FEET DEG/! O0 ~276,17 2697~: ' ':N ,5oo.,oo ,~440,,76 289,2~3) ',N Si, 30~9,72 N ' 1722,42 2685,33 3190,25 N57 19 1779 92 , 2764,56 ~288,00 N 57 1839,16 2846,?! 1903~10 ~ 2935,64 349~54 N $7 2 963 87 3020 45 360 ? 2138208008 13 : 3184 18 ~ 3803 41 N 56 2189 92 3346 ~ 3999 09 N 2238 25 ~ 53 34 W 3089 31 0 70 N 54 4 W 3189 92 0 61 ~ 53 54 W 3287 74 0 34 W 54 20 W 3388 93 2 03 N 54 21. W 3498 38 I 31' 2138 2189 ~ 54 23 W 3602 64 ~ 54 40 W 3702 31 N 55 2 W 3803 34 ~ 55 55 W 3906 15 ~i 56 22 W 3999 04 ~ 56 51W 4086 91 N 57 15'W 4171.98 ~ 55 33 W 4~56.54 N 49 49 W 4341.39 ~ 44 1] W 4427.~4 1 36 0 4 2 47 ! 15 0 SO 0 ¢? 2 O0 3 29 2 31 7676.~2 5909 O0 5flOO.O0 43 50 7815.15 6009 O0 5900.00 44 R 7055.67 6109 O0 bO00,O0 44 42 8096.K3 6209 O0 6100.00 a4 46 8{50.00 624~ 98 6137.96 44 46 )) 44 3 W 4518.59 N 43 17 W 4612.62 N 41 59 W 4708.58 ~ 41 56 W 4804,59 N 41 56 W 4841.03 0,81 0,70 1,42 0,00 0,00 2284 2330 42 2509 2578 2724 2"/53 57 N 3490 73 N 3561 94 N 3629 04 N 3692 5 N 3757 8 N 3824 20 N 389 99 N 395~ O! N 3983 79 W 65 W 434 94 W 442, 4 N 56 34 N 56 31 W 95 W 4518,63 1~ ~ 56 W 79 ~ 56 o,. "o"!'.' "" 22 W 4842, i N 55 ARCO A[,,ASKA, TNC, 2Z-16 KUP~RIIK NORTtt SLOPF3, ALASKA MARK ,F3, R TOP UPPKR BAND GOWKR UPPKR BAND BA~K I,OWER ~AND PDTD TD COMPUTATION DATE: ]OmJUL-85 INTERPOI~ATED VA[,UF,~ FnR CHOSEN HORIZONS MEASUR~]D DEPTH 8EI, OW K B 7510 O0 761b O0 7788 O0 7966 O0 8150 O0 PAGE DATE OF SURV~¥i 7'1'85 KELbY BUSHING EDEVATION: ~09,00 nRZGTN= 1291 FSI~, 327 FEI' SEC 1i,,". TIIN R9E~, UN TVD RECTA NGU~AR ~ COORD l~A TES FROM KB SUB-SEA NOR'TH/$OU~H ,EA~T/WE~T 5989.48 588'0.48 25 t6 N, 0 W 6116.33 6007.33 2656 , '"':'II 1.62 W ,153 25 60'44,25 2683 85 N 3921.~9 W 27,-16 NOR?H ,SLOPE.~A[~ASKA TOP UPPER 8aND PBTD TD MEASUPED DEPTH REDOW K5 7510 O0 7616 O0 7788 O0 7966 O0 8018 O0 8150 O0 109.00 FT SURrAC ORIGIN: 1291FSb, 327 FEI,. SEC il. ~11 . RgE~ OM TVD RECTANGU~AR~COOR,D/NA~E FROM KB SUB-SEA NORTH/SOU~H:' EA6Y/WE$~ 5787.02 5678,02 24 : '3679 3 6!53 25 6044,25 FINAl, WE[,[~ bOCATION AT TD: TRU~ SUB-SEa MEASURED V~RTICA~, VErTICaL DEPTH DEPTH DEPTH ~150,00 6246.96 6137.96 HORIZONTAl, DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4842.01 N 55 20 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2Z- 16 F I ELD KUPARUK COUNTRY USA RUN ONE BATE LOOOEO 7- I-8S REFERENCE 0000?0690 WELL NAME: 2Z- 16 SURFACE LOCATIOw-~- 1291~ FSL, 327' FEL, Sll, Tll R9E, UM VERTICAL PROJECTION -gOOO - 1000 0 0 1000 2000 3000 4000 SO00 6000 ' : : : ; i :: : : : : : ~ P : : , : : : : : I : : : : , : : , ! : : : : : : : ; : , : , , : !- . . , , , , : ' , ; , : : i i!ii Jill" iiii ii~i iiiii iiii iiii iiii !ill iiii !iii !iii iililill~ i i i i } /I i i i i i / i~i /I ITW'i ! i i i i i i ii i i i i i i i~-~T'i? iili i i'i ! ;il ! i !i!i Iii i -i i i i -~ : ;; : ~- . ii! iii ;iii; i i i i i i i i i ; i ~ : i / ; : : rv~-- ; ' ' '-i i ~ - :iiitiiiiliill i'~~il iiii iiii iili iiiiliiii Iiii Iiii iilT'fiill i,iIiIIilL iii i~il'~!il ii~ i~ i i!!! iii!l!i!l iili iiil Ill! il i i ii i!!I ! i! lllli .~ i i: ! ~ ~.i..-~.$.~-4.-P.L~,4-i- .-i.44.4 ~4-~-~- ~4~i-4---~-~ M.4-i~ ~i~-k.L.kL. 4-1-.k4.,-,-.i-.gl..~ -g$4-~.-. -%1 i i i il i i ii~-~-+H'~-+fk, i il i ~ ii i ill ii iiii - il ii ii ii i+~ ~-H..-..+~-4..~H-~%% -J.-M...~- ~.4..L]_ .4-1.~..&~...M-.i-~-&..;-i-LN.-~i-..~L L H ~ ~.. ~ ! i L~. i ~ !-L..LL. -i4.~.L. 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'-~-..'9-~'. --."- . . .~.--?--?'.-?.--.e--'r-.?-~?--.'?.?--.-?---?--~-?-t-.-?-~-?-'r--,..-',---?---?---?..9'.--~-..?...'?? ....... ?--?--.?.-~..'~--.'t.-.?-..?.-.~.., ..4~~.-..;.-.;....L..;--~-. --.i--,;--.~.-~--~,..-4--~.-.b '-.,-~.-----~---~--.G--;-.-~..-J.-~-~--.~. --.;-..6.~--.~..~--~-4..--6,.~----~-..~--4-..,~--...4..-~,...~,..-~, ...... ;,-.,:..~....~.-.~..: ,..;-.~,~.4 ...... ~..-;.,; .... ~.. ,,.. -.-4. ......... ~ ~... ~ ..... ..~*.- ,...;...~... --.,~-G-.-~.--.6 ..-J,---~--~..--4~-.; i ~ ..' I ........ ---.6...D-...-6..-; ..~--~ ~1 ...... ' ..~..~....~...~L_4...4,..-4-~- ....... -..;--.6~ '~' ' --.;-4, ..... ~ -~..-'fl.-6.-.~-.~...-i. ........ ....... ~ .-~-4.-~- t -G--.;..-~.~ .................. .... ';"~""~'-" ...... ;'"~'"~'""~ ...... '~'"";' -'"'" ;' ...... ~ ~ ~'"'~'"~'"'~ "' ~ ' ~ -'rt'~~~' .:-m..- ~ I~--~'-r.:-:-'f-~ .'.-- ~ i mr.-'. ~ i~ F-t~'-:'-?'?l'-?'r=""'?:'"-'F":'"~-? ...... :'":"'?"i'"r': ......... -4000 -DO00 -2000 -1000 0 1000 2000 3000 ERST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WE~L ~Abi~ ~ND' NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Well Histor~ j Samples .,~~-p/ ' - Core Chips , Core Description D irectiona~ Surv~~ .... Drill Stem Test Reports Log Run %~ ', ..... .2, -~ ' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 30, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2Z-16 Dear Mr. Chatterton: Enclosed is a copy of the 2Z-16 Well History to include with the Well Completion Report, dated 6/25/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L45 Enclosure cc: 2Z-16 Well File ,q!aska Oil & (:;as- Cot'ts. ComrnLssion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -10 -14 -16 2X- 1 - 2 - 3 - 4 - 5 - 6 - 7 - 8 2Z- 2 3 6 8 9 11 14 16 223 237 239 83- 84 103 109 118 107 110 113 114 83- 80 85 77 38 85-138 107 109 21239 21253 21255 029-20963 20982 20987 20995 20985 20988 029-20991 20992 029-20960 20964 20957 20924 21377 21379 21361 21363 25645 25645 25653 25646 25653 I! 25646 2576 2576 2579 2577 2579 2577 10 10 12 /15/85 /15/85 /15/85 10/15/85 12/15/85 10/15/85 12/15/85 12/15/85 lO/15/85 12/15/85 lO/15/85 lO/15/85 lO/15/85 10/15/86 lO/15/85 12/15/85 12/15/85 12/15/85 12/15/85 MARK:0093 RECEIVED Co~,lm ...... ~", Alask~ Oil & Gas Cons. '"' ~-~'"" Anchora? MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION ~" DATE: TO: C. rtorl Chai~n FILE NO: TItRU: · Lonnie C Smith ~'--v': ' / ~'.' TELEPHONE NO: Commissioner June 18, 1985 D. HRH. 45 FROM: SUBJECT: Harold R. Hawkins Petroleum Inspector ~7"~{;'f Inspection of Diverter System, ARCO Alaska, Inc., Well No. 2Z-16, KRU Kuparuk River Field. TUesday, June 4,. 1985: i was at the Kuparuk River Field, subject of Other reports~ ~d inspected the diverter system on Nabors Drilling Rig 26-E. I found that there were two automatic butterfly valves, one on each side of the spool below the diverter, both lines from valves were connected together under cellar and out to a common line to pit and teed with two valves to direct flow in upwind directions. (See schematic which is attached). i. I found that the one automatic valve~ was operated to open hydraulicly when the diverter annular was closed, and the other automatic valve was hooked up to the HCR controls. 2. If there was a wash out on the diverter line under the cellar, the flow could not be diverted, as the diverter valves cannot be closed manually and both lines from diverter valves are connected to one line. In summary, I inspected the diverter system on Nabors Rig 26-E and found that it would not operate satisfactory to divert flow safely away and upwind of rig. I talked this over with Lonnie Smith and Blair Wondzell. Attachment 02-00IA(Rev. 10/79) MEMORANOUM State of Alaska TO: THRU: ALASka. OIL- AND GAS CONSERVATION COMMISSION ~/~.~ DATE: C. tterton June 12, 1985 Ch~ FILE NO: ? D. HR/{. 4 0 Lonnie C. Smith -~?f: ~'/ TELEPHONE NO: Commis s loner FROM: SU BJ ECT: Harold R. Hawkins Petroleum Inspector~ BOPE Test ARCO Alaska, Inc., KRU Well No. 2Z-16, Permit No. 85-109, Kuparuk River Field. Monday, June_3, 1985: I left Anchorage to Prudhoe Bay at 3:40 pm by AlaSka Airlines, arriving at 5:10 pm and at ARCO's KRU Well No. 2Z-16 at 11:30 pm. Tuesday, june 4~ 1985: I witnessed the BOPE test, there were no failures . I filled out an AOGCC report which is attached. In summary, when the BOPE tests that Nabors Drilling crew 26E performed for ARCO on Well 2Z-16. They were satisfactory. Attachment 02-00IA(Rev. 10179) O&G tt4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well Operator Location: Sec // T/I~ R~ p M Drilling Contractor .~/.~ fid ~_~ Ri Location, General ~ ~ Well Sign OK ACCUMULATOR SYSTEM General Housekeeping. Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors 0 K Visual Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure I Test Results: Failures ./~ Repair or Replacement of failed equipment to be made within -~ Commission office notified. Full Charge Pressure ~'D 0 psig Pressure After Closure /~'~ ~ psig Pump ifiCr~ hlos~ p~es; 200 psi~ --- min~_~__sec. Full Charge Pressure Attained: .7"/z/~ min~TfO__sec- Controls: Master ff/~ Remote ~/~ Blinds switch cover Kelly and Floor Safety Valves Upper Kell~ Test Pressure ~ ~0 ~ Lower KellM Test Pressure ~ ~ Ball Type Test Pressure ~~ Inside BOP Test Pressure ~?~ Choke Manifold Test Pressure ~~ No. Valves No. flanges ~ ~ Adjustable Chokes ~-~PJO ~drauicall' ~erated choke ~/~ p~' Test Time / hrs. ~, .RftzJ days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~*~y 24, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2Z-16 ARCO Alaska', Inc. Permit No. 85-109 Sur. Loc. 1291'FSL, 327'FEL, Sec. 11, TllN, R9E, UM. Btmhole Loc. l182'FNL, 711'FWL, Sec. 11, TllN, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their.drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated-thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ArtiCle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water~Pol!ution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of -Environmental Conservation. Mr. Jeffrey B. K~win Kuparuk River Unit 2Z-!6 -2- May 24, 1985 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. Where 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~! ARCO Alaska, Inc. Post Office Bo,~ ,00360 /~ncher~ge, Alaska 99510-0360 May 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2Z-16 Dear Mr. Chatterton. Enclosed are- An application for Permit to Drill Kuparuk 2Z-16, along a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on May 27, 1985. If you questions, please call me at 263-4970. Sincerely, A ea Drilling Engineer RECEIVED JBK/LST/tw MAY2 0 198§ Alaska 0il & Gas Cons. Commission PD/L94 Anchorage Enclosures with have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DR ILL E~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE [~]X MULT,PLE ZONI~ 9. Unit or lease name Kuparuk River 10. Well number 2Z-16 11. Field and pool 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1291' FSL, 327' FEL, Sec. 11, T11N, RgE, UN At top of proposed producing interval 1443' FNL, 1105' FWL, Sec.ll, T11N, R9E, UM At total depth 1182' FNL, 711' FWL, Sec.11, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 109', PAD 72' 6. Lease designation and serial no. ADL 25646 ALK 2577 Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 711 feet 2Z-2 well 143' @ 1590' TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8329' MD, 6274' TVD feet 2560 05/27/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2750 psig@__ 80OF Surface KICKOFF POINT 500 feet. MAXIMUM HOLE ANGLE 46°I (see 20 AAC 25.035 (c) (2) 315R psig@ 6!34 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program r SIZE i H°le I Casing ' 24" 16" 12-1/4" Weight 62.5# 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 80' 36' I 36' 4065' 36' I 36' I 35' I 35' 8294' MD BOTTOM TVD 1161 116' 41011 33192 I 8329 i 6274' I (include stage data) ± 200 cf 1100 SX Cold Set III & 450 sx Cold Set II 300 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8329' MD (6274' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig {1800 psi for annular). Expected maximum surface pressure is 2750 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2Z-16 will be 143' away from 2Z-2 at 1590'TVD. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process~.The well will be completed (see attached sheet) 23. I hereby certiJ.~f, hat the foregoing is true and correct to the best o~rm~rl~Kno%:/~c~. ¢~l ¢~ · SIGNED TITLE Area Dr~]]~n En ~neer DATE Th e space b~ ~r ~~o~se'~ CONDITIONS OF APPROVAL Samples required []YES ~..NO Permit number APPROVED BY Mud log required I DirectionaI Survey required I APl number ~YES ~,~q O i J~YES [3NO Form 10-401 (LST) PD/PD94 Approval date ~ 0.,5~ 2 4y/8 ~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 2/4, 1 985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2Z-16 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED A/as/ca 0il & Gas Cons. 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A~ ......... -:--------'i ........ -+-: ............ ,'-: : -----f ......... ....... i ........ _7_D~ ..... : ~ .... -~ ......... -; ........ 4----: :---[ .......................... ~... ........ ~79 ..... : ..... n_. , . . ; · : . . ; , _ --~ : ~ ~ : :__._.~' ;;.~ , :j { -~': -.--VERT/C~L SECTION--['~ :": '.- ~:" .... -"-:---.~--:-~-~-: :-' · ' ---'~ .... ~ .... : -; .... ; ........ ~ ........... : ......... : "~ -J-~-: .............t ..... - i - ~ : , - ........ :-: .... -: .... -~- .... ~-~-~---:-~-~-~: ...... i ......... :-7, ........ ? ......... T-': .... 1. ...... .'' , i .. . ....... :.._...1.,.. '. .... ~_~ ...... -- .-; ...... ~ .......- ....... i ....... CAI_CUI....A'I"i ON r:,l:::' LEAS'r D I.-.:, i ANL. E WELL 1 q"."' . ' ...... . ........ AR _.U ALA..--:,F..A., I Nr:: · "" ii "~ ! '- "1 !'~ i-, -- FIEF .,_9/.'::'/._,,_,.., F:'AO ',;'Z, WELl NO. 16 F. RUF_L:,E:.D Ki_IF:'ARI.IK FIEL. D, NORT'H F-:I_OF:'IE, AI...ASKA CF:~ORI] I NA'I"E:".E;: 1':2'? :l .' C)C) N ::::27.0C) W KB := WEI._I_ 2 ......... AI~ _.U " ......... ' A !_ A.:::, I'...A, I I',IC. FIL. E 177(:) PAD 2Z., .:WEL, I...: NO.: 2 ~":~M'.i::; (S'.i':;) '.. K!..IPAF"dJk:.' F' I.EI..[:~, ':NORTI..I. SLOF":'F., AL_ASI<A COC~RD. IN~]'ES' 1':':'"""::' C)0 N' Z-,,(')F- 00 W KB = RANC. q.Z OF MI:T'ASL.It.RE.D DEF;TH .1. 0'?. 1 C)'~). ..'. WELL 2 · .,. .. · WELL i WELL 2 0. FT l"CI 0. I":T .TID · .:, .)71. F'T W I T FI A 10 C) FT I NT[.--.RVAI .... ./__.,24C), F'T' W I TH A .1. 0,, 0 Fl' I NTEIRVAL.. ,, MEASURED · D E F' T I"'1 , . 1.'660.00 16.--, (.. 00 'FVD RKB .Sr. 1 : NS EW ! 4.79. :':":2 I',1 14.:37 ,, 68 N DISI'AI'4CE BEI'WEEN POINTS IS '14. ::3. :"3 C) F:'T - Eastman ipstock A F~.'TROLANE OOM~ CAI...CIJI~.AT ION OF LEAST DISTANCE BETWEEN WELL 1 --- ARCO AL. ASKA, INC, FILE 2686 PAD 2Z, WELL. NO: 16 PROF'OSED KLIPARUI< FIELD, NOIRTH SLOPE, ALASKA l'l";00RD I NATES: .1. 2.'F; 1.00 N 327.00 W KB ='- WELL 2 .... ARCO ALASKA, INC. F I LE 17 .~ 6 PA D 2 Z, WE L L N FI "- ::3 GM S ( '.=;S ) KUPARUK FIELD, NOR]"I-] F;L. OF'E, ALASI<A COORDINATES: 1876.00 N 633.00 W KB = RANGE OF MEASURED D[.".PTH 10 ?,'. WEI...L 1 0. FT TI] WELL'.,.":' 0 . FT 'TO 65(':,2. FT WITI'-'I A 1,r'i'.O FT INTERVAl._ · 5/:,'.:.)¢1~. FT W I TI-.t A .[ ,[],., 0 FT INTERVAL MEASLIRED TV[I D E F' TI.-I RI< B ~[ 1 N S E W WELL 1 20:"::2. ';..'}:4 187::-:. :1. 0 :1. 612. :":':9 N ::312.64. W WELL 2 1 :'-"::--:0. ('~o .1. :F:7'i.:~. '.:;6 18'7L..,. 2::3 N 6:]::0.26 W [I I '-" I'" · :.TAN_.E BETWEEN F'OINTS !S Eastman - . RECeiVeD · · Alaska Oil & Gas Cons. Corrtmission Anchorao~ 7 6. I _1 i h JIAGP~ #1 13-5/8' 5000 I~SI ~ ~ STAC~ I. 16" - ~ P~Z TN~ ~['ARTIN~ ~ 2,. I1' - ~ P~I C..~II~ ~ 3.,, II ° - ~ I:~I X 13-.r-~,"8' - ~ I1~I SP~ ~ 4. I:~V'8' - ~ PSI Pll~ PJ~ 5,, 1:5-5V8" - ~ P~I CRZI. LI~ ~ ~ ~ A~TOR CAPACITY TEST I. CIEO(AN) FZLL AO3.M. LATCR ~IR TO ~ ~ ~TH HYEN=,NZ. IC FLUID. 2. ASSLRE: THAT A(:O.,MI.A'rl~ PRESStJI~' .IS 3CX30 PSI WITH 5 4 -15-5/8' BOP STACK TEST I. FILL ~ .~I'ACK ~ ~ MN~IF'Q.D WITH ARCTIC DIESEl- 2, C3-~CX THAT ALL L(33( F%LLY RETRACT~ ~I,T TEST PLUG IN N~LLFF_~D WITH 3. CLOSE Nea. L~ PREVENTER AN:) ~ KZLL ~ o-a<E LZI~ V.q..VF.S ADJ~ TO BCP STAQ(. ALL OTI-ER VALVES AM:) Q. iOKES SI.I:U.D BE 4. Pl~~ UP TO 2S0 P~Z AM:) ~ FIR I0 MI:N, IN-. ~ ~ TO 3CX:ID PSI ~ HI3.D ~ I0 I~N, BLEED I:~ TO 0 I~I. LIhE V.q. VES. CLOSE TC~ PIP~ ~ ~ ~ VALVI~ CN KILL .N~ Q.Q<E L.IhES. 6. TEST TO 250 PSI ~ 5CKX) PSI AS IN ~ 4, 7. Cl3~IN, E TESTII~ ALL VALVES, LII~..~ WITH A ~ PSI LOW AM:) 3000 PSI HIGH, 'I~'~T ~ IN STEP 4, ¥ ~o. o.o~ BLZ~D PuV4S ~ 'r~T TO P~I. FLUZD, ~'T ALI. VALVI~ ]N I:~I~LLZNG PO~ZT]:CN, 12. TE~I' S'TAN:~ZPE VALVE~ Kml yo I<EU.Y ~ C~III PIPE .Sq='ETY VALVE.. ~ ZK~ZI:3E: BC~ TO :~300 P~Z. I='CIRM, SZG4, ~ ~ TO CRZII ]:NG Vd~E]<LY ~ F'~ICNALLY t3:~.RATE ~ DAZLY, ARCO Alaska, InC Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Wells 9-16 Dear Elaine: Enclosed is an as-built you have any questions, Si ncerely, d. aruber ^ssociate En§~neer d~/tw location plat for please call me at GRU6/L75 Enclosure Plat - 2Z Pad the subject wells. 263-4944. If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany x: O.G. Elev. 66. P?d Elev. 7t. 1,458" FSL8 FEL Sec. WELL 10 Y=5,966,163.969 Lat. 70° 19'07.0581" X= 529,729.559 L~ ~49°45'32.419'' 0.6. Elev. 66.1' ~ EI~. 71.8' I ~40~FSL WELL ~ 1 y=5,966,~,063 Lat. 70° ~9'06.5366" X= 529,757.5~ ~9.149°45'3~.609" O.G. Elev. 66. Pod Elev. 7~.9' WELL 12 Y=5,~6,057.960 L~ 70° ~9'06.0~51" X= 529,785.556 Long. ~4~ 45'30.797" O.G Elev. 66.~' ~od Elev. 7~.5' 1,298'FSL 75' FWL Se~12 WELL 13 Y=5,9~,889.66Z Lot ~ ~9' 04.3702" X = 529~ 467. 207 Long. ~4¢45'40A06" 0.6. Elev. 66.9' Peal Elev. 7t.9' 1,~31' FSL 244' FEL Se6~ WELL ~4 Y=5~965,942.773 Lot. 70° ~9'04.89~6" X= 529~4~9.~85 Long. ~49°45'40.91~'' 0.6. Elev. 67.0' Pod Elev. 7~.8' l~84'FSL 271' FEL Sec~4 WELL 15 Y=5,9~,~5.892 Lot 7¢ 19'~.4171'' X = 529,4~1.~36 Long. 149°45'41.7~'' O.G. Elev. 67.0' P~d Elev. ~.~' 1,257' FSL 299' FEL Sec. 11 WELL 16 Y=5~966,~8.878 L~. 70°~9' 05.9395" X = 529,38~.~2 Long.~49°45' 42.542" O.G. Elev. 67.5' Pod Etev. 72.~ 1,291' FSL 327' FEL Sec. 11 LOCATED IN PROTRACTED Sec. 11 &I2~TtlN~RgE~ U.M. COORDINATES A SE, ZONE4 SECTION LINE DISTANCES '-' ARE TRUE .... MONUMENTATION 2Z SOUTH,2Z MIDDLE ~ 2Z NORTH~ .... TED ........ PER LHD.~ ASSOC. O.G. EL~V~L~NS~NTERPOLA ;F::.~ ~~~ ~_~_~ FROM S/R DRWG. CE~SZOO-DOU1 /~ , , ~ ~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ' ~~. .t-'L-:';"' & LICENSED TO PRACTICE LAND SURVEYING IN THE ~ 2 ~ D e~ STATE OF ALASKA & THAT THIS PLAT REPRESENTS A SURVEY MADE UNOER MY DIRECT SUPERVISION & ~AT A~ ~TA[S ARE CORRECT AS OF FEB. 17,1985 FOR: WELLS 9-16 ~uporuk ~ro~ct Sor*h Slope ~riHin~ i ~ ~ ,, ~,~( ),~ ,~~ ~~~ DRILL SITE 2Z ~ %¢'~~~ ~ ~ ¢~/:..m CONDUCTOR AS- BUILT ~ ~s LOCATIONS ~,4 ~,, ~ ,8 __--,----Dr°wn By: D-J'W' D'g'n~:NSK9.05.32"' 2. ' IS the":..lease. . 3. Is ~condu'ctOr ' · .Is. enough. C.:..emen' · ' Will i cement/tie 17.~ ppropr: 23. '24. 25. 26. !ui~te'/on ' conductor'...and '.. surface' ,;; ,'.':;', .' '"'~ · iflt'erm~diate).or ..Prbduction:'str~h'gSlj[.'.'. .::'~ Will :.cement'. cover ,all ductive;:~,hOrizons" ,,...' .... ;.; ·; ?, ·; ~ .- -. czaz~ " ' ~.~ ':x:~. -,. . ',~,, ' ' .".. Will s~a.ce casin~ :~ot~c~! ~sb ~a~e~: zones-. .....'; ....... .=... ,. ~ Is-this well-tO: be':'kicked .'off'from an eXisting.~wetlbore:",-;',,;:~'. .... .~.-..' ~band nt " " · . · ··_ Is old. wellbore:': onme procedUre:inc!ud~d'on'~'10-403 .... ~ ..... 'bsepara ' p · . -.-- . ...... ~. Is, adequate~'weltbo tion' ropos.ed ..' ..................... Are necessary.~dtagrams of diverter and'~6~'e~ipment ~ttache~ Does BOPE have sufficient pressure rating - Test to ~,~'FD '' Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ' ional requir 27 "Addit · ements ............................................. .. Additional Remarks: ~).~ ~,~-/~ m/,/..X.. -££ · . Geo log~: Engi~ erio~g: _ rev: 03/13/85 .: . i /' /511 INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. .., · .. Oil & Gas Cons. Anchorage SERVTCF ".t ,,:", 'v, E VEP$ .T. [)~'! '~ : n.~,"r' E : ~R EV T (.)I~,% F' 'f i., t::;' m mm m~ ! m~ m~ -m mm m ~m m TYPE CATE; SIZE Cor',~E OhO 000 0.15 065 OhO 000 On5 0¢,5 9 n () 00 O 0 n 7 0 ~, 5 0 n 0 000 00 2 0 6 5 00 ,;) 000 003 065 000 OOO 002 065 O~O 000 On7 065 V('O 000 uq6 065 OOO 000 003 065 On,') oo0 O0 I 065 = 2.260 ~ .57.0 DF = 2.~1..70 ra 57,0 OF' = ?.380 ~ 57.0 DW - 077 ra 14,!,. ,O~ 1 1 1 1 ,.1. 1 1 1 1 68 00000000000000 6.8 00000000000000 68 OHO00000000000 68 00000000000000 68 OnO00oO000000, O 68 00000000000000 68 00000000000000 68 00000()00000000 68 00000000000000 68 00000000000000 68 O000000000000O 68 OOt) O0000000000 68 000000000000()0 68 O00OO0000000(lO DATA 0 E P T .500 n..o, (.i f.,, 0 ."'.., F 1'., ~.i ~ '.:~ p W '.t b o. 3' 41 8 ~,~ C u b t. f~ '/n qgP'I ~70n . r'. C- 0,~ SP -2°. 437b 7 (') q 9 r, !.? 0 () . ~. '~ i, 25 ;S4. :2 ~; () P. 7.4093 q 0 % t> 95 O,n3P2 276° . 7P. a375 2 ~ 0 a, r. U 0.1. 'a53., 57. PCr: b 3~ 'L, B TUn FC l. br~ 2 . 4434 -360.7500 3.7793 -1598 . 0000 ~. 6074, 1 ()4. 3125 ~.qboO 471. ?5O9 9.7539 9e.31.75 4,,043o 441.0000 7.6758 84..500t) 79g. OOnO ~.2031 90.56?5 ?.~164 QgP,O[)O0 7.6211 7~.~375 ?.00~2 770.5(>n0 1~.5938 67.1250 I[,1¢ 3.291~S CAI.,1 8. 5000 P i",iP A 3,999.2 'Tb~ 2.7383 CA, I,I t O, 30/~ 7 q!'~RA 4,1094 TBS" 9.7129 Cai,1 10.37~0 Pi~RA 4.2383 Tb~; 7. g5 1 t) rqI, I g. 2,969 R~,,P A 3. 1426 T i.. ~-" 6.33 ;~ 0 CALI 8.7109 P~'~PA 3. 0870 Ibp' 7. FtO 08. CALl q. 398 4. o!,~RA 3.11,91 Th~¢ 1 2, CAf,,[ 9.0938 SP SP OE:OT S P RHOB E P T SP HOb SP nEP'I' SP Sp ~'PH 1 Sp ~p~,~], SP 2.621 !. 1.21 ,3125 ,c.;, 90 · ~ 500 6(.On. n ~)~,.) Y4b T:d 4. ! 445 -j'q. ~gg"? (:R 1 _,'jqo... . . ?b'~',,. , "I(:~"L -oga. '! b r? ~:R A T 'I !., n l L n T I.~ F R a. '!' ~"' C .~',! L, ! C R F C t',,,~ L T i- D UNJ~ t' 2 94.9 .'2. 3 566 2 123 3 3 !.32 3 5 '73 3 -g99 -r)90 -999 2 -q9g -999 2 -099 -o9o 2 -g99 -99q -999 -999 -09° 3 -990 -099 -c)99 3 ,-099 . g 1 Q 9 .261 '7 ,0000 ,,~' , ~ 000 .1,445 .8125 .5000 .7500 ,O000 .7500 .25oo .2500 .7578 ,2500 .2500 .4375 .7500 .2500 .191.4 .2500 ,25.n0 . ?5OO .1152 .2500 .2bO0 .2500 ,2500 ,2500 .2b09 .9531 .2500 .250~ .25n0 T IJ M CA! :t R I'..i R a T L~',:' C .A L: I R :!q R A l L,~~' C A L P N ~' A c.A!, I R' N R A T .L H P, NP, A :r L M CAI,i T b t~' P I'qP A T ("TAT. 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