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211-152
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OJQQQIC U a m Q 2 2 a111 N_ N_ _N N_ U0 0U co a '�.O 0 0 0 (V (NJN N N N OO O i Z I�,N N N N N < /Z 104 = 1 co= E as I... in O o r > I co o J U m a) �Y O Q a5 4-) 0 L I\ a 0 0 0 m a :° �a Om J 0 °' ° mE rn m w Naz o- , it, IX Q 000N �. O co LE E I 0 o N U o ?E CD Cr) J co E NZ co H w cn Q lil 0) in .2 0 0 N a _m = E I, CL o CIS 20 I► co a UN v /Z 0 � m r } } g_ Q o s/ to M�� E I— I— ~ N _ c O Z N N cu C Z` (9 CO a):� 7.i E Y •C = Cl) Q co Ci N UC O C aPk le Q as ) .1.111 • co c •- a Q o. o m O Z EO N U T I m U 0 2 0 % I IEC 0 N _s Z a '2co . N• a f0 , E cu Z 2 Z o 71 6.c. o D co E W g / m N O in N I c > 6 e- W y y N N N �'' W t O t d O. m re o c '> l0 a Y cC T. o 0 in 2 in E v 1111 E E 6 or TAS I�j, s THE STATE Alaska Oil and Gas 8ofAL1 1 V}Gk Conservation Commission.0 mR. GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese Wells Engineer ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2K-08B Sundry Number: 313-514 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this i day of October, 2013. Encl. ill • STATE OF ALASKA %1' I ' RECEIVED AL...,<A OIL AND GAS CONSERVATION COMMION � APPLICATION FOR SUNDRY APPROVALS 5EP 2 d 0i3 20 AAC 25.280 drs )0 7 I (-3 1.Type of Request: Abandon r i Plug for Redrill r Perforate New Fool r Repair well r ChangA©GG• lam r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAtter casing g r Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 1. 211-152-0 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20111-02 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F7 2K-08B- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588,25589 Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9545 6191 9318' 6044' 7297' none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 115' 115' Surface 3735' 9.625" 3771' 2905' Intermediate 7393' 7" 7434' 5227' Production 2219' 4.5" 9441' 6098' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5" L-80 7222 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HRD ZXPN LINER TOP PACKER MD=7222 TVD=5097 NIPPLE-X NIPPLE MD= 505 TVD=505 • 12.Attachments: Description Summary of Proposal • F,i 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17. Service r 14.Estimated Date for Commencing Operations: ...., ivr 15. Well Status after proposed work: 10/X2013 le/2-0 //3 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 265-4250 Email: Tyson.M.WieseAconocophillips.com Printed Name Tyson Wiese / Title: Wells Engineer Signature Phone:263-4250 Date Cl/P)X1013 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3(3. 5/ Plug Integrity V BOP Test r Mechanical Integrity Test r Location Clearance Other: �G 717;Cc/ /✓] s GG�v '- cls /Kid' G4 /-rd Ga�z0 ✓G� �' , , P d /D7dccvi-vi r'71- el/it-off CG��� rr �vl� Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /c — 40 P APPROVED BY Approved by: C467 41.4.,1----- COMMISSIONER THE COMMISSION Date: /� ` /0— / Approved is valid tocol I tl1s tornh�dit.e of approval.up �b Form 10-403(Revised 10 2012 G N A Submit Form and Attachments in Du licate A\11,o\'RBDMS OCT 11 1 ( Jo/8 / l 3 , We�,3 \� 2K-08B Plug and Abandon Permit to Drill #: 211-152-0 The objective of the proposed 2K-08B Plug and Abandon is to free up the space on the pad to allow replacement well 2K-34 to be drilled as close as possible to the old 2K-08B surface location, allowing ConocoPhillips to capture the remaining hydrocarbon resource in the area, as part of the A-sand redevelopment plan. 2K-08A was drilled/cased in the Kalubik shale. CTD had 3 failed sidetracks from the 2K-08A wellbore, due to difficult drilling/completing through this shale interval, as shown in the schematic. Plug and Abandon Procedure: Slick Line/ LRS: (Diagnostics) 1. RIH and obtain updated 30 min SBHP @ approx. 9,250' KB. 2. Perform injectivity test to ensure adequate rates for cementing through retainer. 3. Dummy drift for 4.5" cement retainer to 7,300' KB. Ensure drifts freely. B&F if needed. 4. Set plug/catcher in nipple @ 7,168' KB. MIT-T and MIT-IA to 1,500 psi. Pull DMY valve from mandrel @ 7,115' KB. Confirm circulation to the IA for cementing. Pull catcher/nipple plug @ 7,168' KB. RDMO. Coil Tubing: (A/C Sand Isolation Cement Plug) 1. Ensure the 10-403 Sundry has been approved by the AOGCC. 2. RIH and locate the 4.5" X nipple (3.813" ID) @ 7,168' KB. Flag pipe. 3. RIH and set cement retainer @ approx. 7,297' KB. (middle of 1st full joint below SBE) 4. Perform Injectivity test to ensure adequate rates for cementing operations. (+/- 2 BPM) 5. Pump/Squeeze 40 bbls of 15.8# cement into the failed CTD sidetracks and 4.5" Liner. 6. Unsting from retainer and lay in of 15.8# cement to GLM #5 @ 7,115' KB. 7. Fill/Lay in 16 bbls of 15.8# cement into Tubing and IA, to a planned TOC of 6,722' KB. 8. POOH, freeze protecting tubing from 2,000' KB to surface. RDMO Slick Line / LRS: (Tag/Test 1st plug) 1. WOC at least 24 hours prior to tag and test. 2. Notify the AOGCC (AOGCC.Inspectors@alaska.gov) of the timing of the cement plug tag and PT. Provide at least 24 hour notice. 3. Tag TOC @ approx. 6,722' KB. (500' cement plug above packer) 4. Test cement plug (MIT-T and MIT-IA) to 1,500 psi. DDT Tubing & IA. Record Results. E-Line / LRS: 1. RIH and perform CBL from tag to surface. Locate TOC in IA. Shoot tubing holes approx. 50' above TOC in IA. Circulate diesel to confirm communication. RDMO. Schlumberger Pumping Services: (Fullbore Cement Job) 1. Pump 144 bbls 15.8#cement through tubing holes, bringing TOC to approx. 2,500' KB, in Tubing and IA. Slick Line / Little Red: (Tag/Test 2nd plug) 1. WOC at least 24 hours prior to tag and test. 2. Tag TOC @ approx. 2,500' KB. Test cement plug (MIT-T and MIT-IA) to 1,500 psi. DDT Tubing & IA. Record Results. RDMO. TW E-Line / Little Red: 1. RIH and perform CBL from tag to surface. Locate TOC in IA. Shoot tubing holes approx. 50' above TOC in IA. Circulate diesel to confirm communication. RDMO. Schlumberger Pumping Services: 1. Pump 10:J .ibis AS1 cement through perf holes, bringing cement to surface in Tubing and IA. WOC for at least 48 hours. Perform MIT's and DDT's on T/I/O. Conoco Drilling Toolhouse / Schlumberger Pumping Services: (Surface Abandonment) 1. Remove Well House. Bleed off T/I/O to ensure all pressure is bled off the system. 2. Excavate around wellhead, gaining access to casing strings. Note: If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 3. Cut off the wellhead and all casing strings at 4 feet below original ground level. Document cement tops. 4. Perform Top Jobs to verify that cement is to surface in all casing/tubing strings. Add cement as required. OGCC Witness Kequirea to connrm cement to surface. 5. Photo document the top of the well (casing cemented to surface), prior to welding on the marker plate. 6. Send the casing head w/ stub to materials shop for repair/redress. Photo document. 7. Weld 1/4" thick cover plate over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2K-08B PTD#: 211-152-0 API #: 50-103-20111-01 8. Remove Cellar/Shoring Box. Back fill excavation with gravel/fill to ground level. 9. Obtain site clearance approval from the AOGCC. RDMO. 10. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo Document final location condition after all work is completed. TW TW 9-23-2013 2K-08B Plug and Abandon PTD #: 211-152-0 Summary: Planned P&A 1.)Set catcher/plug in nipple profile tb,7.168'KB and obtain TOC 3rd Plug(AS1)@ Surface MITT and MIT-IA. Pull DMY 16'11-40 62.5011 Conductor 115'KB GLV from 7,115'KB.Circulate Al diesel to IA. Pull catcher/plug 3.813'X Nipple @ 505'KB from 7,168'KB. TOC 2nd Plug(Class G)@ 2,500'KB N 2.)DMY drift for cement retainer \, to se do Caliper to ensure clean section of pipe cement OA Shoe TOC from original completion est.@ 2,771'KB. \ retainer set depth.B&F if needed //� to drift freely. // 3.)RIH and set cement retainer 9 5/8'J-55 36a Surface Casing0 3,771'KB 7.297'KB. Perform Class G N. \\ Cement CT Squeeze through \ retainer to plug the two failed • CTD A and C Sand laterals.(3r°is GLM's: •• � \ already isolated with CIBP) DMY 0 3,098'KB \ DMY 0 4.733'KB \\ \ 4.)Unsling from Retainer and lay DMY 0 5,830'KB cement in Tubing and IA through DMY @ 6,598'KB \ \\ open GLM.to planned TOC of OPEN 0 7,115'KB \ \� 6,722'KB. T Tubing \\�� \, 5.)WOC for 24 hours. Tag TOC `�� and Perform MIT-T and MIT-IA to test cement plug with AOGCC \� witness. Perform DDT on T and IA. TOC 1"Plug @ 6,722'KB » ../ 6.)Run CBL to locate TOC in the / / IA. Shoot holes in tubing 50' , above TOC.as close to mid joint as possible. Confirm Circulation 3.813"X Nipple 0 7,168'KB //// rates for cementing. / f 7.)Pump fullbore Class G . , / / cement job to bring TOC to Baker HRD Liner Top Packer wI 10'PBR @ 7,222'KB approx.2,500'KB(below base of permafrost). Tag and Test after t>t 1 24 hrs. s -a Cement Retainer 0 7,29T KB 8.)Run CBL to find TOC in IA. Shot Holes 50'above TOC. Pump AS1 cement Job from 7"J-55 26k Casing Window 0 7,434'KB(Plugged back wl / 2,500'KB to surface. cement,and milled out of original 7"casing during 2011 RST) 9.)Perform MIT-T and MIT-IA. Perform TWO DDT. Prep area for 3-4'z'monobore Wellhead Dig and Removal. osj -_- 9.316whipst',9cks,345'et,and1 _ c2KO88PB3. C. 4'/:CIBP @ 9,365' 2K-088-PB2:9,346'-9,595' Stuck 3 :"Liner @ 9,348'-9,392' %111111111111119.316'-9,545' Stuck BHA @ 9,318'-9,370' 4 1.4"L-80 12.60#Liner from 7,224'KB-9M4'KB 2K-08B-PB1:9,419'-9,680'(difficult drilling.kalubik shales) TW Ferguson, Victoria L (DOA) From: Wiese,Tyson M <Tyson.M.Wiese@conocophillips.com> Sent: Tuesday, October 08, 2013 3:50 PM To: Ferguson,Victoria L(DOA) Cc: Allsup-Drake, Sharon K Subject: RE:2K-08B Abandonment(PTD 211-152, Sundry 313-514) Attachments: 2K-08 P&A 10-403 Sundry Attachment Updated 10-8-2013 tw.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached is the updated 2K-08 PM Summary. I have included the steps below and will also include those steps in the final procedure as well. Like we had talked about, the planned start date will most likely be 3 weeks out, as I have to complete/review the PM procedure, and obtain Partner approval before we can proceed. If there is anything else you need, let me know and I can work on getting it to you Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1-907-263-4250 Cell:1-907-230-5388 From: Ferguson,Victoria L(DOA) [mailto:victoria.ferguson@)alaska.gov] Sent:Tuesday, October 08, 2013 2:40 PM To: Wiese,Tyson M Subject: [EXTERNAL]2K-08B Abandonment(PTD 211-152, Sundry 313-514) Tyson, For this abandonment, please include steps for the surface abandonment including: 1. Excavation around wellhead 2. Cutting of casing/tubing strings 3. Top off all annuli and tubing with cement—AOGCC witness 4. Photo documentation of the top of the well before welding on the marker plate 5. Weld marker plate with required information—AOGCC witness 6. Photo documentation of the welded-on plate 7. Back fill excavation and top excavation 8. Obtain site clearance approval from AOGCC 9. Photo document the final location condition Thanx, Victoria Victoria Ferguson 1 • 2K-08B Plug and Abandon Permit to Drill #: 211-152-0 The objective of the proposed 2K-08B Plug and Abandon is to free up the space on the pad to allow replacement well 2K-34 to be drilled as close as possible to the old 2K-08B surface location, allowing ConocoPhillips to capture the remaining hydrocarbon resource in the area, as part of the A-sand redevelopment plan. 2K-08A was drilled/cased in the Kalubik shale. CTD had 3 failed sidetracks from the 2K-08A wellbore, due to difficult drilling/completing through this shale interval, as shown in the schematic. Plug and Abandon Procedure: Slick Line/ LRS: (Diagnostics) 1. RIH and obtain updated 30 min SBHP @ approx. 9,250' KB. 2. Perform injectivity test to ensure adequate rates for cementing through retainer. 3. Dummy drift for 4.5" cement retainer to 7,300' KB. Ensure drifts freely. B&F if needed. 4. Set plug/catcher in nipple @ 7,168' KB. MIT-T and MIT-IA to 1,500 psi. Pull DMY valve from mandrel @ 7,115' KB. Confirm circulation to the IA for cementing. Pull catcher/nipple plug @ 7,168' KB. RDMO. Coil Tubing: (A/C Sand Isolation Cement Plug) -. aF °; 1. Ensure the 10-403 Sundry has been approved by,the AOGCC. 2. RIH and locate the 4.5"X nipple (3.813" ID) @ 7,168'RB flag pipe^ 3. RIH and set cement retainer @ approx. 7,297' KB. (middle of 1st full join-tib-Wow-SBE) 4. Perform Injectivity test to ensure adequate rates for cementing operations. (+/- 2 BPM) 5. Pump/Squeeze 40 bbls of 15.8#cement into the failed CTD sidetracks and 4.5" Liner. 6. Unsting from retainer and lay in 3 bbls of 15.8#cement to GLM #5 @ 7,115' KB. 7. Fill/Lay in 16 bbls of 15.8#cement into Tubing and IA, to a planned TOC of 6,722' KB. 8. POOH, freeze protecting tubing from 2,000' KB to surface. RDMO Slick Line/ LRS: (Tag/Test 1st plug) 1. WOC at least 24 hours prior to tag and test. 2. Notify the AOGCC (AOGCC.Inspectors@alaska.gov) of the timing of the cement plug tag and PT. Prov ffe at least 24 hour notice. 3. Tag TOC @ approx. 6,722' KB. (500' cement plug above packer) 4. Test cement plug (MIT-T and MIT-IA) to 1,500 psi. DDT Tubing & IA. Record Results. E-Line / LRS: 1. RIH and perform CBL from tag to surface. Locate TOC in IA. Shoot tubing holes approx. 50' above TOC in IA. Circulate diesel to confirm communication. RDMO. Schlumberger Pumping Services: (Fullbore Cement Job) 1. Pump 144 bbls 15.8#cement through tubing holes, bringing TOC to approx. 2,500' KB, in Tubing and IA. Slick Line/ Little Red: (Tag/Test 2nd plug) 1. WOC at least 24 hours prior to tag and test. 2. Tag TOC @ approx. 2,500' KB. Test cement_plug(MIT-T and MIT-IA) to 1,500 psi. DDT Tubing & IA. Record Results. RDMO. COtiCv�. ZIP'26/ qed OBJ 74' tet ' h %ve,e he�e�' TW �� T7jereiocei 7ut�e `f 40 PO'm !Pseu?S T�sf- �/( e/ei46 /c5r- ptie. to Me cksimeei of 7 ) ty,",dw'/-e /of e, / 71340 E-Line / Little Red: 1. RIH and perform CBL from tag to surface. Locate TOC in IA. Shoot tubing holes approx. 50' above TOC in IA. Circulate diesel to confirm communication. RDMO. Schlumberger Pumping Services / Conoco Drilling Tool House: 1. Pump 105 bbls AS1 cement through perf holes, bringing cement to surface in Tubing and IA. WOC for at least 48 hours. Perform DDT on T/I/O. 2. Contact COP Tool House to begin Surface Excavation and Final Wellhead P&A." TW 9-23-2013 L I+ ERSE,DED 2K-08B Plug and Abandon PTD#: 211-152-0 - Summary: ,a.-..�... Planned P&A 1.)Set catcher/plug in nipple profile a 7,168'KB and obtain TOC 3rd Plug(AS1)a Surface MIT-T and MIT-IA. Pull DMY 16"1140 62.50#Conductor @ 115'KB Aill e tr 16. GLV from 7,115'KB.Circulate 3.813"X Nipple @ 505'KB diesel to IA. Pull from 7,168�KB catcher/plug TOC 2nd Plug(Class G)@ 2;600'KB „",r 2.)DMY drift for cement retainer .,, toK Caliper ensure cleanansection B a of pipe cement OA Shoe TOC from original completion est.@ 2,771'KB. ‘..-...,,:,„ .4.,..,,,,,..\.4\ retainer set depth B&F if needed 2: •\.,,..:: _;\\\r to drift freely. \ �..":s':\\ 3.)a RIH and set cement retainer 9 5/8"J-55 36#Surface Casing @ 3,771'KB /,�\� �\�•, F r @ 7,29T KB. Perform Class G \\;`\�:�\ Cement CT Squeeze through S\`• retainer to plug the two failed \,,�\* CTO A and C Sand laterals.(3'is GLM's: \.�`\.‘-',‘.`,: '° already Isolated with CIBP) DMY @ 3,733'KB •\�\'.\••\, �•. 4, Unstin from Retainer and DMY @ 5,830'KB '\ `_4 .. ) 9 lay DMY @ 5,830'KB �'\ cement in Tubing and IA through DMY @ 6,598'KB .,\` .i�,.. \ ,\y open GLM to planned TOC of OPEN(�7,115'KB �\\•;;N" 6,7fo KB. F.P Tubing `. *� 5.)WOC for 24 hours. Meg TOC :Z::,‘;',',',‘,;::::, and Perform MIT-T and MIT-IA to � .�,ti\ test cement plug with AOGCC , Z witness. Perform DOT on T and IA. TOC t"Plug Q 6,722'KB j�'•\,,..j',,,‘7,",,,,,,.. ,-.'„ ;1.'7.Y ff"/.' rfi % 6.)Run CBL to locate TOC In the / IA. Shoot holes In tubing 50' './/4/'2',44"-4-'././"."., ;',f /f rd/`. 5,v above TOC,as close to mid joint fi r/��"�Y� as possible. Confirm Circulation 3 813"X Nipple @ 7,168'KB %f//�`" " p2 rates for cementing. i4-,,,,,;;;;;%,:%;.,:/,...; f////4 /;2- /7,----;2:-.- .)Pump fullbore Class G 4f/!�'��/ cement Job to bring TOC to Baker HRD Liner Top Packer w/10'PBR @ 7,222'KB - f _ approx.2.500'KB(below base of -2--;44*" - permafrost). Tag and Test after •tri• I, 2d hrs. Cement Retainer @ 7,297'KB8,)Run CBL to find TOC In IA. Shot Holes 50'above TOC. ;11":;:%",/,-;;11!. Pump AS1 cement job from 7"J-55 26#Casing Window @ 7,434'KB(Plugged back w/ ,r.�'r',!j;; 2,500'KB to surface. cement,and milled out of original 7"casing during 2011 RST) % /.f t.�r,. 9.)Perform MIT-T and MIT-IA. 'rrl.r`„ Perform 111/0 DOT. Prep area for 3-4',"monobore -....1-7..------....- Wellhead Dig and Removal. whipstocks set @ 9,316',9,345'.and 9,419', /,'rte 4 W CIBP @9,385 2K-08B-PB2-9,346'-9,595' Stuck 3'l:"Liner a 9,348'-9,392' Filill2K-08B-PB3:9,316'-9,545' Stuck BHA @ 9,318'-9,370' 4W L-80 12.60#Liner from 7,224'KB-9,444'KB 2K-08B-PB1 9,419'-9,680'(difficult drilling,kalubik shales) McMains, Stephen E (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday,August 21, 2013 11:01 AM To: McMains, Stephen E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Missing Data 211-152, KRU 2K-08B Steve—As we discussed over the phone, the story behind KRU 2K-08B (211-152) is a bit complicated. I'm sending this note explain what happened and to provide some extra info to complete your records. Please refer to the attached schematic diagram. Well 2K-08A(211-049) is a rotary sidetrack of 2K-08 that TD'd at 9444' MD and was completed with 4W cemented liner in early 2011. Our intention for the 2K-08B (211-152)was to sidetrack out of the 4W liner and install 3W cemented liner across the Kuparuk sands. As the schematic shows, three different times we cut a window in the 4W liner and drilled to planned TD but we never were successful in getting 3W liner installed. We named these three failed attempts 2K-08B- PB1, PB2, and PB3 as reported in the 10-407 submitted on 2/7/12. We were never able to make a successful 2K-08B completion, and the present 2K-08A completion remains in Suspended status. ConocoPhillips is still evaluating options for the long term disposition of 2K-08A. As per your request, for the completion of Block 4A of the 10-407 we are providing TD coordinates for the 2K-08B-PB3 plugback which was the last unsuccessful drilling attempt for PTD#211-152. Please let me know if you need any further information. • Total Depth of 2K-08B-PB3: 4379' FNL, 1420' FEL, Sec. 3, T1ON, R8E, UM 1 ' ( p�- a''' • • 0 1111 "W All Z glg 1:3ILI v- V WW2 0 W Lc 00 a c, w Z z v V a It ca O a CO WI Ce �a. 2 tn Z Q Q. H •- CO A .... ... 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U Y Y N N N C a� cep coCOC UUi V M V V V 0- ►© M U NO CD U) N OM) N N N 0 A N C0 W 0 0 O O Lo O N N N C f— 0 C T 2 N CO CO. M 'V ' O Cp N ^ © Q Si 7) d CO CO O 0) D) O m 0) 0) 0) U E o :3 0 0 y c U d co s u) 2K-08A Final CTD Schematic 16' 62.`_0 H-40 at 115'MD Iisanse 1.- XppIe(3 813"10)at 505' 4-1/2", 12.6#1-80.I8T-ModTt, IW Camco KB G-2-1R gas ht mend 5830',6598'.8 7115` 9'/'.36*.1 at X-apple(3813"ID)at 7160 3771'MD EEO loom_ 4-12"locatorvlseals at 7219' Muleshoe at 7930' WNW 4"/" mer 7222'-9, "HR I" PIILinertop packers vandovi in 7'.26$. -- "DG"Flex lock Liner hanger at J-SS at 7434'MD —gm ' 80-40 WE at 7256' Landing C oltar at 9348' Float Collar at 9381' E Z.Ream sho eat 9440' 4 Y:'m onobore rhipstocks a 9316%9345'8941V' `-.. CIBPat 9365' �••.• ••••4y� 4 � 4'/;',12 6a.L-80 final ► 7222%944411D • 46 2K-088-PB3 9316'-954 Stuck Coirrrak BS 49318'-9370' • 2K-086-PB2 j // 9345'.9595" Stuck 3Wliner 9348%9392' / 2K-08B-P1619419'-9680' From: Allsup-Drake, Sharon K Sent: Tuesday, August 06, 2013 9:28 AM To: 'McMains, Stephen E (DOA)' Cc: Eller, J Gary; Venhaus, Dan E Subject: RE: Missing Data 211-152, KRU 2K-08B Steve - I need to discuss this with Gary Eller, the engineer on this well, and he will be back in the office in a couple of weeks. Sharon 263-4612 2 From: McMains, Stephen E (DOA) [mailto:steve.mcmains@alaska.gov] Sent: Monday, August 05, 2013 1:48 PM To: Allsup-Drake, Sharon K Subject: [EXTERNAL]Missing Data 211-152, KRU 2K-08B Sharon, Missing data from well completion report. Form 10-407 Block 4A has no footage for the producing depth or for the bottom hole location. Please email this information to AOGCC along with the state plane coordinates. The Completion Report 10-407 Form shows the well as SUSPENDED. I didn't Gary Ellar address so please let him know. Steve McMains 793-1233 3 McMains, Stephen E (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Tuesday, August 06, 2013 9:28 AM To: McMains, Stephen E (DOA) Cc: Eller, J Gary;Venhaus, Dan E Subject: RE: Missing Data 211-152, KRU 2K-08B Steve - I need to discuss this with Gary Eller, the engineer on this well, and he will be back in the office in a couple of weeks. Sharon 263-4612 From: McMains, Stephen E (DOA) [mailto:steve.mcmains(aalaska.gov] Sent: Monday, August 05, 2013 1:48 PM To: Allsup-Drake, Sharon K Subject: [EXTERNAL]Missing Data 211-152, KRU 2K-08B Sharon, Missing data from well completion report. Form 10-407 Block 4A has no footage for the producing depth or for the bottom hole location. Please email this information to AOGCC along with the state plane coordinates. The Completion Report 10-407 Form shows the well as SUSPENDED. I didn't Gary Ellar address so please let him know. Steve McMains 793-1233 1 2K-08B PTD 211152 API 50-103-20111-02-00 rte` BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2K-08BPB3 RUN NUMBER (mandatory, FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 7/1/2012 TODAYS DATE: 02/14/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital il ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UI- PHIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. i 1 I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC ( I 1 I 1 I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 1 I 1 I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 2K- TD 211152 API 50-103-20111-02-00 lred BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandat. WELL NAME 2K-08BPB2 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 12/27/2011 TODAYS DATE: 02/14/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur THIN I S #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 I 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 I 1 I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT 1 State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 2K-4101D 211152 API 50-103-20111-02-00 Vaal BAKER PRINT DISTRIBUTION LIST 2'2ci`i HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes WELL NAME 2K-08BPB1 RUN NUMBER FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) COUNTY North Slope Borough _ BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 12/23/2011 TODAYS DATE: 02/14/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digitalCD ADDRESS(FEDEX WILL NOT DELIVER TO PD.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #OF THIN 15 #OF COPIES #OF COPIES v„ 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP 1 1 1 1 I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP T 1 T 1 I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Page 1 of 1 sib 41. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, February 02, 2012 10:22 AM To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA); McMains, Ste.•=- SOA) Subject: 2K-08A and K-08B (PTD 211-049 an.daft Gary, We (Steve, Dave and myself) sat down and discussed the reporting dilemma regarding 2K-08 and have come to a final decision: 2K-08A needs a 407 report with it P &A'd as a final status. (As soon it was sidetracked with CTD for the 2k-08B it was abandoned technically). This closes out this PTD . (K-08B)eeds a 407 reporting it as suspended. You have all the drilling reports/directional to us already so just need a redone 407 page. There will be PB1, PB2 and the final failed attempt would be called 2K- 08BPB3 as you have done already. The two other PTDs (2K-08BL1 and 2K-08BL1-01)should be withdrawn (can be done by an email request) since they will never be drilled. When you decide to reenter the well the next wellbore will be 2K- 08C and at that time 2K-08B will be closed out by P &A ing it. I hope this makes sense ... please call me with any questions. This was an unusual well sequence so I apologize for the inconsistency on our part. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/2/2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑✓ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillipsAlaska, Inc. orAband.: January 11,2012 211-152/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 December 20,2011 50-103-20111-02 4a.Location of Well(Governmental Section): 7.Date TD Reached: 1 14.Well Name and Number: Surface: 121'FSL,94'FEL,Sec.2,T1ON,RO8E, UM not retie.] X01\ 2K-08B,2K-08BPB1,2K-08BPB2,2K-08BPB3 Top of Productive Horizon: 8.KB(ft above MSL): 146'RKB 15.Field/Pool(s): not r ch tl '4/ GL(ft above MSL): 118'AMSL Kuparuk River Field Total Depth: _, 6 Aw�., 3`s'11� 9.Plug Back Depth(MD+TVD): not reached g ia(lli3 ,�..m_ l 9318'MD/6044'TVD j� Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates, 27): 10.Total Depth(MD+TVD): Ce 1 v 16.Property Designation: Surface: x-498310 y- 5938425 Zone-4 � � neEscbed C5 L(3 i ADL 25588,25589 TPI: x-na y- na Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-na y- na Zone-4 none 2674,2675 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1464'M/1424'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 9318'MD/6044'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 35' 115' 35' 115' 24" 179 sx AS II 9.625" 36# J-55 35' 3770' 35' 2905' 12.25" 1100 sx AS III,520 sx Class G 7" 26# J-55 41' 7434' 41' 5227' 8.5" 230 sx Class G 4.5" 12.6# L-80 7222' 9441' 5097' 6098' 7" 310 sx Class G ' 24.Open to production or injection? Yes ElNo Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 7222' 7222'MD/5097'ND none RECEIVED ri__:` V f 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED FEB 0 8 2012 7601'-8357' 204 sx Class G $ �l�* 7900'-8500' 185 sx Class G Alaska Oil&Gas Cons. Commission 6830'-7482' 140 sx Class G Anrhnrage 7301'-7581' 63 sx Class G 27. PRC DUCTION TEST Date First Production Method of Operation Flowing,gas lift,etc.) suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated . 01L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA it Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS FEB 0 8 2012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 71.--- 3.12 �` ..e1 ,-& c. 28. GEOLOGIC MARKERS(List all formations and m< encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1464' 1424' needed,and submit detailed test information per 20 AAC 25.071. 2K-08BPB1 total depth 9680' 6187' 2K-08BPB2 total depth 9595' 6199' 2K-08BPB3 total depth 9545' 6191' N/A Formation at total depth: none 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Printed Name L. ntt Title: CTD Engineering Supervisor Signature ' Phone 263-4021 Date z/7//Z Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 CV N Jv Q 0 bo Io ' -0 M ` Q N co N NV 1-1 N a) r N 3 N- n OE in M ca Y � N in ~ 3 .-"° asp' m y Q) t co To , o0) • O) O N M NC J N [6 d) in J N in 3 a) N J y n _ a) 00 7/ 40 - 00 O '65 L Z 00 a) co O L O co O as Q O N EN Y °° a a cN °) m rnO m ITL oL0 n - r J - LU c a) I _- (V C n (V N c 0 _ O RI 4 \ 200 m cu c.-\6 � X 4 U X 4 ..ur _ = CO J E. W 0 N. co rn Co M a) Q r— CO Y M i0 CO -4- I- a.. a L b /\ mrnU co N O N O co co CL co co i 1";:2b .,- s cr i 440. , z. ...z. ... ........ > co . v ,,, i /: 3 Ci) r r .,, . . 1 1- __ \ 1 U as tc N '., oL� U Oel co N t a) V o I v 3 rn ``) Q n M Q) CO 2 " - r o °� 0Daa) csi - M2 4t-CIh c co cn •E d N w Y \ co m \ N , M = N a) coM V m U N a) (n V I- ConocoPhillips Time Log & Summary W'ellview Web Reporting Report Well Name: 2K-08 p Rig Name: NABORS CDR2-AC 0-11) Job Type: DRILLING SIDETRACK Rig Accept: 12/13/2011 10:00:00 PM Rig Release: 1/12/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/13/2011 24 hr Summary Move from 2K-28 to 2K-08. NUBOP's &hard lines. Begin reel swap. Rig Accept at 22:00 HRS. 06:00 22:00 16.00 0 0 MIRU MOVE MOB P RDMO from 2K-28 and spot rig on 2K-08. Lay down containment, Build tree scaffolding, NU BOP's and hard line in cellar. 22:00 00:00 2.00 0 0 MIRU WHDBOCTOP X ***Rig Accept***Start removing hardline from the reel&presure bulk head. 12/14/2011 Change out 2"CT reel with 2 3/8"Reel&install new drive bearings. Remove 2"Gooseneck and install 2 3/8" Gooseneck.Start changing BOP&Injector sizes. 00:00 02:30 2.50 0 0 MIRU WHDBO CTOP X Lower out 2"reel onto Peak bed truck. 02:30 05:30 3.00 0 0 MIRU WHDBO RGRP X Start removing Bearings from reel stand. Finish up in cellar. ***used 3 hours rig maintenace time*** 05:30 06:30 1.00 0 0 MIRU WHDBOSFTY X Crew change, PJSM 06:30 07:30 1.00 0 0 MIRU WHDBO RGRP X Complete bearing swap. ***Use 1 hour rig maintenance time*** 8 hours of 12 remaining on rig maintenance time in December. 07:30 09:00 1.50 MIRU WHDBO CTOP X Try Lifting Gooseneck through V-door with no luck. Prep reel area for lifting 2 3/8"CT string. 09:00 09:15 0.25 0 0 MIRU WHDBO SFTY X PJSM 09:15 13:15 4.00 0 0 MIRU WHDBOCTOP X Lift reel into rig, and secure into saddles. 13:15 17:30 4.25 0 0 MIRU WHDBOCTOP X Make up iron inside reel. Continue rigging up. 17:30 18:30 1.00 0 0 MIRU WHDBOSFTY X Crew change-PJSM for lifting gooseneck over wind walls with Crane. 18:30 21:00 2.50 0 0 MIRU WHDBO CTOP X Swap gooseneck's. 21:00 00:00 3.00 0 0 MIRU WHDBO CTOP X Start redressing BOP's&Injector for large pipe&BHA handling. 12/15/2011 BOPE test waived by Chuck Sheevey. Continue with 2 3/8"swap,stab pipe. Change out Bravo 1 valve, &start testing BOP's. Low 250 psi/high 4500psi. Page 1 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 0 0 MIRU WHDBO CTOP X Change out Injector Brass&gripper blocks to 2 3/8". Change out BOP Rams: PS-2 3/8", Deployment-3",VBR, PS-2 3/8".Clean up rig floor. 05:00 06:00 1.00 0 0 MIRU WHDBO CTOP X Dress CT string for stabbing pipe. 06:00 06:30 0.50 0 0 MIRU WHDBO SFTY X Crew change, PJSM 06:30 10:00 3.50 0 0 MIRU WHDBO CTOP X Internal grapple connector for stabbing CT needs to be machined down in order to fit the 2 3/8"ID. Functiion test BOP's,grease valves, Continue preping for BOPE testing. **Identified small crack on gusset of inner reel drum. Nabors welder repair. 10:00 13:00 3.00 0 0 MIRU WHDBO CTOP X MU internal grapple to CT, prepare to stab CT, and stab CT 13:00 14:30 1.50 0 0 SURPRI WELLPF BOPE X Grease stack and rig valves.MU BOP test joint 14:30 15:30 1.00 0 0 SURPRI WELLPF BOPE X MU pressure bulk head,prepare to BOPE test 15:30 21:30 6.00 0 0 SURPRI WELLPF BOPE X Start BOP test. B1 leaking. Repair valve. Fix air line running to doghouse from Kummi.Valve check list. BOPE test time start 21:30 22:30 1.00 0 0 SURPRI WELLPF BOPE X Function test BOP's-PJSM start testing BOP's Low 250psi-High �� 4500 psi. have to re-tighten lower �` swab valve flange after filling the ,/ stack. ���///VVV 22:30 00:00 1.50 0 SURPRI WELLPF BOPE X Continue testing 12/16/2011 Complete BOP test. Pump slack, pressure test PDL, CT reel iron, PDL&Tiger tank line. Pull BPV. Flow check good. P/U BHA#1 Coiltrak assembly with 2 7/8"XTreme motor,jars,accelerator&3.80"Tri-cone bit. 00:00 04:30 4.50 0 0 SURPRI WELLPF BOPE X Continue with BOP test from Step 7. Low 250 High 4500 psi. Passed all BOPE tests. 04:30 06:00 1.50 0 0 SURPRI WELLPF PRTS X Pressure test PDL's&Tiger tank lines. 06:00 06:30 0.50 0 0 SURPRI WELLPF SFTY X Crew change 06:30 06:45 0.25 0 0 SURPRI WELLPF SFTY X PJSM 06:45 07:15 0.50 0 0 SURPRI WELLPF PRTS X Pressure test Tiger tank line.500psi. 07:15 07:45 0.50 0 0 SURPRI WELLPF SLPC X Check stripper rubber(good). RU to pump slack management 07:45 08:45 1.00 0 0 SURPRI WELLPF SLPC X MU injector head to well. Fluid pack CT 42.5 bbrls. Pressure test Stripper and inner reel valve. Reverse circulate an additional 20bbrls. Heard cable moving. RU to cut CT 08:45 09:00 0.25 0 0 SURPRI WELLPF SLPC X PJSM Page 2 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:30 0.50 0 0 SURPRI WELLPF SLPC X Cut CT,found cable at 12'.finding markings on pipe. 09:30 10:30 1.00 0 0 SURPRI WELLPF CTOP X Align gooseneck, install BHI depth counter 10:30 11:30 1.00 0 0 SURPRI WELLPF SLPC X Cut total of 70' CT. Pipe looks good. No markings. RD CT cutter 11:30 12:00 0.50 0 0 SURPRI WELLPF SLPC X RU to install CTC, and pull BPV 12:00 12:30 0.50 0 0 SURPRI WELLPF SFTY X Crew change, PJSM 12:30 14:30 2.00 0 0 SURPRI WELLPF PULL X PT BPV lubricator 950psi. Bleed down to 250psi. Open well, Pull BPV fished on second attempt. (195psi on well). RD BPV 14:30 17:30 3.00 0 0 SURPRI WELLPF CTOP X MU CTC, Pressure bulk head not testing. Rehead psi bulk head. Bleed down well to Opsi. 17:30 19:00 1.50 0 0 SURPRI WELLPF SFTY X Crew change&Pre-spud meeting with Gary Crew. 19:00 20:30 1.50 0 0 SURPRI WELLPF CTOP X Mig cable-good test-pressure test bulk head and CT connector to 4000psi. 20:30 22:00 1.50 0 0 SURPRI WELLPF OWFF X PJSM for P/U BHA#1. Lower& warm up top drive. Circulate warm sea water across the top of the stack, return line slushy. Good SW across the Stack. Zero psi-Open well for no-flow test. Light gas/air migration but no pit gain. Monitor for 30 minutes. No-flow. 22:00 23:30 1.50 0 72 SURPRI WELLPF PULD X Start making up&Lower in BHA#1. 23:30 00:00 0.50 72 400 SURPRI WELLPF TRIP X Open EDC and break circulation to Tiger tank. Increase pump rate to 1.5 bpm while RIH.Weight check and pipe inspection at 400ft. IA 117/OA 60 psi. 12/17/2011 Mill with 3.80"Tri-cone from 9334'-9426'. POOH&P/U 4.5"Hailey U/R with 2.81"Mill. RIH tie in+12ft correction. 00:00 03:00 3.00 400 7,000 SURPRI WELLPF TRIP X RIH pumping SW @ 1.3 bpm,weight check and pipe inspection at 3000' 27K. RIH-P/U&inspect pipe at 6000'Weight 39K. RIH weight 20K. 03:00 04:00 1.00 7,000 8,500 SURPRI WELLPF DLOG X CCL logging from 7000'@ 1000 fpm. for 420ft.Correlate to GLM 7115'& pup Start pumping used flo-pro. IA 460psi /OA 440. RIH to 8500'. Stop pumping close EDC. 04:00 05:00 1.00 8,500 8,790 SURPRI WELLPF MILL X EDC closed. Correction+12ft. P/U 100'-weight 47K with SW on backside. RIH and start with FCO/Milling looking for a tag or motor work. 15 fpm-2.0 bpm,circ 2100, BHP 3022,WHP 90(tiger tank), CT weight 19K,WOB 0 Page 3 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:30 0.50 8,790 9,100 SURPRI WELLPF MILL X Started seeing WOB with no motor work. Bring returns into pits @ 8900'. 2.0 bpm, circ 2500, BHP 3600,WHP 0,WOB.25, ROP 10 fpm,CT weight 19K. Heavier Mud 10.5#coming over shakers @ 9000'. 05:30 06:15 0.75 9,100 9,334 SURPRI WELLPF MILL X Weight check @ 9100'-43K. RIH continue milling FCO. Mud in pits increased from 9.8 to 10.1 ppg. 06:15 07:00 0.75 9,334 9,334 SURPRI WELLPF MILL X Get WOB at 9334'. PU weight= 45k. Increase rate to 2.3 bpm. Milling with 2850 psi pump, 5k WOB, 16k surface but getting level 3 vibrations on CoilTrak. Cut rate to 2.1 bpm,2550 psi,&level 2 vibes. Stacking WOB. PU several times 44K PUW. Getting rubber& aluminum in returns(landing collar). 07:00 09:30 2.50 9,334 9,335 SURPRI WELLPF MILL X RIH 9333.7'.Time mill with 1.5-2K WOB.2.12 BPM,2450 CTP, 17K CTW,3642 BHP 09:30 09:45 0.25 9,335 9,336 SURPRI WELLPF MILL X Stall PU 52K.Weight drop off 45K. li _PUH 60'. RBIH 4 ' 09:45 10:00 0.25 9,336 9,336 SURPRI WELLPF MILL X Cont milling 3-4K WOB,2.12 BPM, _2560 CTP, 19K WOB,3665 BHP 10:00 10:06 0.10 9,336 9,338 SURPRI WELLPF MILL X Weight drop off, PU for weight check. Q rT 49K. RIH.down to 9338. �yV'^� 10:06 10:21 0.25 9,338 9,340 SURPRI WELLPF MILL X Cont milling 7K WOB,2.12 BPM, 2550 CTP, 15K CTW 10:21 11:03 0.70 9,340 9,351 SURPRI WELLPF MILL X Stall PU 50K,weight drop off. 45K (AA, off bottom psi 2350 CTP,470 diff. RBIH.Cont. Milling 9339.5. 0 WOB, 10-20 FPH ROP. 11:03 11:18 0.25 9,351 9,351 SURPRI WELLPF WPRT X Pump 10bbrls high vis sweep, Weight check 45K.Chase sweep back to 9100'RBIH. 11:18 12:00 0.70 9,351 9,367 SURPRI WELLPF MILL X Cont. milling down,30 FPH,0 WOB 12:00 12:15 0.25 9,367 9,368 SURPRI WELLPF MILL X Increased WOB at float collar. 12:15 12:36 0.35 9,368 9,378 SURPRI WELLPF MILL X Weight dropped off. Cont.milling down 30 FPM,0 WOB 12:36 12:45 0.15 9,378 9,383 SURPRI WELLPF MILL X Bypass MM&MP choke to blow back. Lots of rubber over shakers. Cont milling down 30 FPH,0 WOB 12:45 13:12 0.45 9,383 9,393 SURPRI WELLPF WPRT X Pump high vis sweep 10 bbl, PUH 47K Chasing sweep up to 9155'. RBIH 13:12 14:24 1.20 9,393 9,427 SURPRI WELLPF MILL X Tie in depth to gamma point. Note: +6'correction. Did not change depth. Cont milling down. 14:24 17:24 3.00 9,427 72 SURPRI WELLPF TRIP X Mill down to WOB increase(shoe)at 9426.7'. POOH circulating at 2.1 bpm. 17:24 18:30 1.10 72 0 SURPRI WELLPF OWFF X Crew change,flow check well. Page 4 of 30 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:30 2.00 0 59 SURPRI WELLPF PULD X Lay down BHA Inspect bit-total of 5 teeth broken,worn&missing on bit. P/U BHA#2 with Hailey 4.5"U/R& 2.81"AER mill. 20:30 00:00 3.50 59 9,250 SURPRI WELLPF TRIP X RIH with EDC open pumping 1.2 bpm.Tie in with+12 ft correction to GR marker at 9219'. Close EDC& Weight check 48K not pumping. RIH 12/18/2011 U/R from 9335'-9437', made three passes 3-5 fpm. P/U Dummy WS run clean drift to TD. P/U&Set 4.5"MonoBore Whipstock.TOWS 9420' BOWS 9435.7'.Good set,set down 5K. POOH for window mill. 00:00 00:30 0.50 9,250 9,437 SURPRI WELLPF DLOG X CCL log from 9300'to TD. +4ft vs tally depth.Tag 9437'-P/U 100ft. 00:30 02:30 2.00 9,437 9,437 SURPRI WELLPF UREM X Start U/R from 9335'-1.5 bpm, 2700, BHP 3550, Diff 1200psi,WOB 0,Ct weight 19K, ROP 3-5 fpm, down to 9437'Make 3 passes up/down. P/U weight 43K. Little to no motor work. Light cement returns in B/U. 02:30 05:00 2.50 9,300 59 SURPRI WELLPF TRIP X EDC Open-POOH pumping 1.5 bpm. 05:00 06:00 1.00 59 0 SURPRI WELLPF SFTY X Flow check/No flow-PJSM& Lay down BHA. 06:00 06:30 0.50 0 0 SURPRI WELLPF SFTY X Hold Pre-Spud meeting with day _crew.Crew change, PJSM 06:30 07:30 1.00 0 0 INTRM1 RPEQPI PULD X PU BHA 3,WS drift 07:30 10:00 2.50 79 9,266 INTRM1 RPEQPITRIP X RIH 10:00 10:15 0.25 9,266 9,266 INTRM1 RPEQPI DLOG X Tie in depth with gamma, correct +10' 10:15 10:21 0.10 9,266 9,436 INTRM1 RPEQPI TRIP X Cont RIH to TD.Tag TD without any set downs 10:21 12:51 2.50 9,436 0 INTRM1 RPEQPITRIP X POOH 46K CTW 12:51 13:06 0.25 0 0 INTRM1 RPEQP1SFTY X At surface,flow check, PJSM. 13:06 14:06 1.00 0 0 INTRM1 RPEQPI PULD X LD BHA 3 14:06 15:06 1.00 0 0 INTRM1 RPEQPI PULD X PU BHA 4(whipstock) 15:06 17:24 2.30 84 9,219 INTRM1 RPEQPITRIP X RIH 17:24 17:36 0.20 9,219 9,436 INTRM1 RPEQP1DLOG X Tie into GR marker, +11'correction. 17:36 18:06 0.50 9,436 9,436 INTRM1 RPEQP1WPST X RIH, close EDC. PU weight=48k. RIH,tag bottom at 9437'. PU to string weight+1'. Orient WS to 30 deg ROHS and set WS. TOWS= 9429'M D. 18:06 18:15 0.15 9,436 9,420 INTRM1 RPEQP1WPST X Bring pumps up-CT weight 41K, WOB 1.7K, Set at 3800psi,3.5K increase WOB. RIH set down additional 5K. P/U weight 45K 18:15 20:45 2.50 9,420 84 INTRM1 RPEQPITRIP X POOH pumping through EDC. Flow check at surface. PJSM for laying down BHA. Page 5 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:30 1.75 84 104 INTRM1 RPEQPI PULD X Lay down WS assembly-Setting tool looked good. P/U 3.80"window milling assembly .with 30.55'2 3/8"PH6 joint. 22:30 00:00 1.50 104 7,500 INTRM1 WHPST TRIP X RIH with EDC closed pumping .4bpm. 12/19/2011 RIH tag early at 9377'Work through.Tag TOWS 9419'. Mill window with clean exit and drifts.TOW=9419, BOW 9427,TD 9444'. Pump 12.5 KWF,while POOH BHA hung up at 9342'Work down, pull free-POOH to inspect BHA. 00:00 01:45 1.75 7,500 9,377 INTRM1 WHPST TRIP X RIH with 3.80"DSM window mill& string mill.Tie in+9ft.Tag early @ 9379'. P/U weight 46K.Tag early again 9377'.Set down 4K. Float collar area. 01:45 02:30 0.75 9,377 9,250 INTRM1 WHPST TRIP XT P/U and orient Lowside-pumping .5bpm.Tag 9377'. P/U orient HS increase pump rate to 1.1 bpm, slowly work down. Stall/shut down @ 9378'heavy P/U 53K. Negative 8K WOB. Dragging something up. Relax to zero,Orient low side, P/U and popped free. 02:30 03:15 0.75 9,250 9,419 INTRM1 WHPST TRIP XT RIH pumping 1.8 bpm, lowside.Slow down from 9367-9382'-Clean-RIH to 9410' P/U through section.Clean. Shut down pumps-RIH tag WS 30 ROHS @ 9419.2ft. 03:15 04:00 0.75 9,419 9,419 INTRM1 WHPST MILL XT P/U start milling. Free spin 2.5 bpm, 2800 psi,Ann 3690,diff 400ps.CT wght 19K. Milling-2.5 bpm. Stall early, acting the same as 9377'. Overpull-relax to nuetral and orient tool lowside. P/U and drag a couple of feet, popped free. P/U Orient 30 ROHS 04:00 07:00 3.00 9,419 9,421 INTRM1 WHPST MILL X RIH to mill -2 bpm,time mill from 9418.60'30 ROHS. 2 bpm,2340, BHP 3614, Diff 370, Ct weight 22K, WOB.7,time milling. No problems with junk like previous. 07:00 11:00 4.00 9,421 9,426 INTRM1 WHPST MILL X Increase pump rate to 2.3 BPM,start choking back MP choke for 12.5 ECD. Cont. Milling.2850 CTP, 3.5K DHWOB, 1 FPH 11:00 13:30 2.50 9,426 9,428 INTRM1 WHPST MILL X Continue milling 2780 CTP,2.2K DHWOB,2.3 bpm, 1.1 fph, 12.4 ppg ECD. 90%metal and cement in returns, 10%shale. 13:30 16:00 2.50 9,428 9,433 INTRM1 WHPST MILL X Increase ROP 2 FPH.2700 CTP, 232 WHP, 19K CTW, 1K DHWOB. 16:00 18:30 2.50 9,433 9,444 INTRM1 WHPST MILL X 50%shale, 50%cement in sample, Increase ROP 5 FPH,2800 CTP, 230 WHP,3-4K WOB, 12.5 ECD. Page 6 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 9,444 9,444 INTRM1 WHPST REAM X Complete milling OH-Samples= 20%Cement,50%shale,35% claystone. Start Backreaming holding MPD. P/U weight 45K.Start taking returns to TT for mud swap. TOW=9419' BOW=9427' TD=9444' 19:30 20:00 0.50 9,444 9,360 INTRMI WHPST REAM X Dry-passes. First just window-clean, Second P/U 9360'30 right HS-drift through window-Clean passes. P/U weight 44K. 20:00 21:30 1.50 9,360 9,360 INTRM1 WHPST CIRC X Open EDC and Circ KWF targetting a 12.5 ECD,slowly cycling pipe, taking dirty milling fluid to TT.When cycling CT had 10k overpull on WOB sensor at 9344', near landing collar. RIH finish with final 30 bbls of KWF. 21:30 22:00 0.50 9,342 9,344 INTRMI WHPST TRIP XT KWF to surface,Close EDC-flow check. EDC 12.8 static. BHP 3900psi.Work dry in/out making head way down 15ft. Pump.7 bpm. Popped free through first collar. Discussed with town engineer, decided to pull BHA and continue on with drilling ops. 22:00 00:00 2.00 9,344 2,800 INTRM1 WHPST TRIP X POOH pumping through mill-KWF at surface. Formate coming back 12.1 - 12.2. 12/20/2011 Had difficulty drilling ahead @ 9444'.Attempt different pump rates and WOB's with no success. Drill down to v 9454'.TOOH and had large amount of shale come over the shakers. Inspected BHA,motor appeared to be in good shape. Bi-center bit was packed with clay. 00:00 01:30 1.50 2,800 102 INTRM1 WHPST TRIP X POOH pumping 12.5#KWF. Flow check at surface. 01:30 02:30 1.00 102 0 INTRM1 WHPST PULD X PJSM for laying down BHA. Small pieces of Alum.found in mill&string mill.3.79"No-go, 3.80"go. 02:30 03:30 1.00 0 0 INTRM1 WHPST CIRC X Close swabs and jet stack,function valves. 03:30 05:00 1.50 0 83 INTRM1 DRILL PULD X PJSM-P/U drilling BHA with 2 7/8" X-treme&3.75 Bi-center 05:00 08:00 3.00 83 9,400 INTRM1 DRILL TRIP X RIH with EDC closed pump min. rate. 08:00 10:08 2.14 9,400 9,400 INTRM1 DRILL CIRC X Drift down to 9400' HS toolface. No problem.Open EDC, Swap well from 12.5ppg KWF to 10.5ppg Drilling Mud, using a 10bbrl high vis 12.5ppg Formate spacer. 10:08 10:14 0.10 9,400 9,444 INTRM1 DRILL TRIP X Close EDC,Trip into well 10:14 10:32 0.30 9,444 9,445 INTRM1 DRILL DRLG X 9444', Drill Ahead,2.5 BPM @ 3045 PSI FS,659 PSI Diff., BHP=3930 10:32 10:50 0.30 9,445 9,400 INTRM1 DRILL WPRT XT PUH to casing to sort out MWD problem with DGS and USR. Problem software related,everything back up and running Page 7 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:50 11:02 0.20 9,400 9,445 INTRM1 DRILL WPRT X Wipe back into hole to drill,stack out at 9430', PUH Run right through 11:02 14:32 3.50 9,445 9,454 INTRM1 DRILL DRLG X 9445, Drill Ahead,2.70 BPM @ 3400 PSI FS, BHP=3950,Acting like bit balling,geo has shales and clay in sample, Do mini wipers,Try different pump rates and WOB, Pump 20BBL Drillzone pill, little help with ROP 14:32 14:50 0.30 9,454 9,100 INTRM1 DRILL WPRT X Wiper trip into casing, pulled heavy @ 9432, continue wiper, BHA Pressured up liked plugged bit, Cleared itself 14:50 15:26 0.60 9,100 9,250 INTRM1 DRILL WPRT X Run back in hole,tag up twice @ 9430, PUH to tie in 15:26 15:32 0.10 9,250 9,270 INTRM1 DRILL DLOG X Log tie in for zero correction 15:32 15:44 0.20 9,270 9,454 INTRM1 DRILL WPRT X RIH, Set down @ 9430, Rolled pump at Min rate from 9428 to get through 15:44 16:08 0.40 9,454 9,454 INTRM1 DRILL DRLG X 9454', Drill ahead,2.70 BPM @ 3400 PSI FS, Unable to make any footage 16:08 17:02 0.90 9,454 9,428 INTRM1 DRILL WPRT XT PUH and backream 9435 to 9428 2 times, 180 degrees out from as drilled,saw 9430'area running back down on second downward pass at as drilled TF 17:02 20:29 3.46 9,428 0 INTRMI DRILL TRIP XT 9430'area looking better,Trip out to reconfig BHA.Get a large amount of shale over the shakers when @ 500'. Clog off choke,samples sent to geos. 20:29 23:59 3.50 0 0 INTRM1 DRILL PULD XT Tagged up.Conduct pre-job. Pressure undeploy BHA. Inspect BHA, motor appears to be functional, Bi-center bit packed with clay 12/21/2011 Run 3.80"D331 diamond mill, no obstuctions. Drilled ahead from 9450'to 9461'. Recovered large amount cuttings(mostly shale but also metal)on TOOH. Drilled ahead with 3.75"x 4.125 bi-center bit. ROP increased from 10 to 40 FPH @ 9507'. Sample confirms Kuparuk C sands. 00:00 01:45 1.75 0 83 INTRM1 DRILL PULD XT Conduct pre-job for pressure deploy. Pressure de-ploy D331 drilling BHA. 01:45 04:30 2.75 83 9,260 INTRM1 DRILL TRIP XT RIH with 3.80"D331 mill, EDC closed pumping.41 BPM.Tie in for a +4'correction. 04:30 04:54 0.40 9,260 9,451 INTRMI DRILL TRIP XT Continue RIH,to 9450',to drill ahead. No problems in problem areas,Slight bobble @ 9429' 04:54 07:54 3.00 9,454 9,461 INTRM1 DRILL DRLG XT Tag at 9451'. Mill junk-10'of hole, 2.6 BPM @ 3131 PSI FS, BHP=3970 07:54 10:24 2.50 9,461 80 INTRM1 DRILL TRIP XT 9461, Milled 10',Trip out, PUW=47K, 2.8 BPM,At-1700'started unloading shales and metal from wellbore,cleared up-400. Page 8 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:24 14:24 4.00 80 83 INTRM1 DRILL PULD XT Tag up,close EDC, PJSM, LD cleanout BHA#7. Configure BHA#8 Drilling BHA with 0.5 degree motor and Hughes Bi Center. Replace check valves in UQC. Inspect drilling choke for debris or damage. PU BHA#8.Make up to coil and surface test. 14:24 16:39 2.25 83 9,240 INTRM1 DRILL TRIP XT RIH with drilling BHA#8 16:39 16:45 0.10 9,240 9,266 INTRM1 DRILL DLOG XT Log tie in for+13 16:45 17:15 0.50 9,266 9,438 INTRM1 DRILL TRIP XT Trip in,Close EDC @ 9333,Trip through window pumping min rate. Go to 9438'take weight and motor work. PUH through window to get free spin. Differential pressure higher then normal 17:15 17:30 0.25 9,430 9,461 INTRM1 DRILL FCO X Run back through window to drill 3.6 BPM @ 3600 PSI FS, BHP=4070. Tag up @ 9430'drill off and go through. Work rate up to 1.5 FPM and head for bottom. 17:30 21:45 4.25 9,461 9,496 INTRM1 DRILL DRLG X Tagged bottom @ 9461',drill ahead 21:45 22:00 0.25 9,496 9,496 INTRM1 DRILL WPRT X Perform BHA wiper,pick wt 44k and clean. PUH to 9435', RBIH back to BTM with no problem. 22:00 00:00 2.00 9,496 9,527 INTRM1 DRILL DRLG X Drill ahead,2.6 BPM @ 3674 PSI. 11 ROP. Drilling picked up @ 9507' upto 40 ROP. Had a pump stall out @ 9510'in C-sand. Had some gas to surface,go to tiger tank for 20 bbls and cir out gas. 12/22/2011 Drill down to 9528',perform wiper to swab. Large amount of solids including large rocks. RBIH,drill ahead to 9680'. Pipe became stuck @ 9465'while on wiper trip. Free up pipe with mineral oil pill but hung up in the window @ 9423'. Broke injector cart drive line&injector drive shafts while working pipe. Repaired drive line, injector shaft repair on going. 00:00 00:11 0.19 9,527 9,528 INTRM1 DRILL DRLG X Continue drilling, lost high line power @ 00:03 while drilling @ 9528.89'. Trap pressure with choke. Get generators started up. ECD dropped as low as 11.5 ppg. 00:11 03:30 3.32 9,528 1,770 INTRM1 DRILL WPRT X Get power back on, pick off bottom 47k. Back on the pumps. Decided to do long wiper to swab. Pump HI/Low sweep. PUH,min rate up thru window. Get another gas bubble to surface,take it to tiger&cir out 20 bbls. Continue wiper up to surface. 03:30 04:54 1.41 1,770 82 INTRM1 DRILL WPRT X Near surface start getting a large amount of material over the shakers. Chokes clogging off, have to shut pump off temporarily,surge choke to get cleared up. Pump back on, have sample of large rocks. Continue wiper up to the swab. Page 9 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:54 07:06 2.20 82 9,240 INTRM1 DRILL TRIP X RBIH 07:06 07:18 0.20 9,240 9,265 INTRM1 DRILL DLOG X Log Gamma tie in for+4 07:18 07:30 0.20 9,265 9,465 INTRM1 DRILL TRIP X Trip in, stop @ 9400'and close EDC, 07:30 07:36 0.10 9,465 9,479 INTRM1 DRILL DLOG X Log RA Marker in whipstock, RA=9431,TOWS=9419, BOW=9423 07:36 07:48 0.20 9,479 9,528 INTRM1 DRILL TRIP X RIH at min rate.Set down then passed through @ 9430 07:48 11:54 4.10 9,528 9,680 INTRM1 DRILL DRLG X 9529',drill ahead,2.6 BPM @ 3400 PSI FS, BHP=3954, ECD=12.8 11:54 12:06 0.20 9,680 9,465 INTRM1 DRILL WPRT X Wiper to window, PUW=47K 12:06 14:36 2.50 9,465 9,518 INTRM1 DRILL WPRT XT Hung up at 9465', unable to go back down put able to circulate. Able to orient,Seeing DHWOB stuck below 9414'. Pump Lo/Hi Vis sweeps. Motor is in stalled condition. Pump 10 bbl mineral oil.2 bbl out of coil work pipe, No good. Trap pressure and soak 20 minutes. Work pipe down and push free and RIH. 14:36 15:36 1.00 9,518 9,630 INTRM1 DRILL WPRT X Circulate out mineral oil while building more sweeps. Hung at 9518 while coming up. Start to trap pressure while pipe in compression and pop out down. Still building sweeps moving pipe. 15:36 16:36 1.00 9,630 9,600 INTRM1 DRILL WPRT X Start Lo/High sweeps down coil recip pipe while circulating sweeps to surface. 16:36 17:28 0.88 9,600 9,423 INTRM1 DRILL TRIP X 9600', Head for cased hole,2.72 BPM @ 3750 PSI FS, PUW=46.7K, BHP=4055. Hang up in BOW @ 9423'. Work it. Injector cart moved: coupler on cart drive shaft broken. Get mechanic to fix. Unable to move pipe while repairing drive chain. 17:28 20:58 3.50 9,423 9,423 INTRM1 DRILL TRIP XT Continue to circulate @ 1.5 BPM while cart drive chain is getting fixed. **Start Nabors down time @ 18:00. 20:58 21:28 0.50 9,423 9,443 INTRM1 DRILL TRIP XT 9423', ready tp move pipe again. Back rate to.4 BPM, move downhole to 9443'. Unable to move chains on injector to POH.Trouble shoot. 21:28 23:58 2.50 9,443 9,443 INTRM1 DRILL TRIP XT Suspect drive shafts on injector are broke.C all out mechanic,stand by until mechanic arrived.Confirmed that both shafts are broken. Pull 2 new shafts out of the spare injector in the shop.Work on shaft replacement. **End Nabors downtime @ midnight. Page 10 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12/23/2011 24 hr Summary Free stuck pipe from 9423'&POOH.Cut pipe and performed slack management. RIH with clean out assembly(D331 mill with up cutters).Tagged in window area @ 9420'. Mill down with moderate motor work to 9427. Function tested BOPE. 00:00 00:30 0.50 9,443 9,443 INTRM1 DRILL TRIP XT Continue working on replacing injector shafts. 00:30 03:15 2.75 9,443 9,423 INTRM1 DRILL TRIP XT Repairs finished. Get pipe moving up very slowly,49k to 53k. Hang up again @ 9423'. Work wt up to 60k. Change up pump rates. Open EDC, pump @ 3 BPM to help clean debris. Move pipe periodically. 03:15 04:15 1.00 9,423 9,393 INTRM1 DRILL TRIP XT Pump 10 bbl mineral oil pill. Get several bbls out of bit,work pipe up, no good. Able to get pipe moving down. Pull and hang up in same place. Shut down pumps&let mineral oil soak for 15 minutes. Pull up to 60k,slack off not going down hole. Increase pump rate,pull up and wt.finally broke over,start POOH. 04:15 07:15 3.00 9,393 79 INTRM1 DRILL TRIP X POOH to surface. 07:15 09:15 2.00 79 0 INTRM1 DRILL PULD X At Surface, PJSM, LD drilling BHA #8 09:15 11:15 2.00 0 0 INTRM1 DRILL SLPC X PJSM, R/U to cut 200'for coil fatiigue mgmt 11:15 15:15 4.00 0 0 INTRM1 DRILL SLPC X Crew change,valve check list, PJSM. R/D cutter, Boot coil end. Prep for slack mgmt, reverse circulate coil. Cut 70'coil to find wire, prep coil and install CTC, Pull test to 40K 15:15 17:45 2.50 0 0 INTRM1 DRILL SLPC X Make up e-line head and test UQC, PT to 4K 17:45 18:00 0.25 0 0 INTRM1 DRILL BOPE X Function test BOPE 18:00 19:30 1.50 0 0 INTRM1 DRILL PULD XT Change out, PJSM. PU cleanout BHA#9 with 3.80"D331 with cut-rite backcutters. 19:30 21:45 2.25 70 9,220 INTRM1 DRILL TRIP XT With EDC open Pump @ 1 BPM While RIH 21:45 22:00 0.25 9,220 9,257 INTRM1 DRILL DLOG XT log, +6'correction.Close EDC 22:00 00:00 2.00 9,257 9,427 INTRM1 DRILL FCO XT RIH, pump 1 BPM thru window tag @ 9420'&stall motor, repeat several times. Mill by slowly,stall pump @ 9427'. 12/24/2011 Stacked&stalled out in the open hole @ 9470'. Pulled wiper to window,stuck pipe @ 9430'.Worked pipe +/ and able to free pipe. Run dummy whip stock drift to 9385'. Page 11 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 9,427 9,433 INTRM1 DRILL FCC XT 9427'Continue RIH,slow easing down. 2.45 BPM @ 3506 PSI. Stacking weight in some places on the way down. Stack out&stall @ 9470'. Pull wiper up to 9428'. RBIH and stack wt immediately. Stuck- unable to go up or down. Appears that motor is turning. 02:30 05:15 2.75 9,433 9,433 INTRM1 DRILL FCC XT Lost circulation due to packoff. Bullheading fluid @ 1.5 BPM. Line up&pump down the back side. Equalize annular/bore. Pressure up well head,work pipe. Surge choke, no good. Line up down coil @ min rate. Try to establish circulation. Start seeing some returns. Step up rate slowly,start losing returns over 1 BPM. Keep circulation @ 1 BPM. Get Mineral oil pill made up. 05:15 06:00 0.75 9,433 9,433 INTRMI DRILL CIRC XT Start pumping mineral oil dowm coil @ 1 bpm. Returns at 0.6 bpm. 06:00 08:15 2.25 9,433 9,433 INTRM1 DRILL FCC XT Mineral hole coming out of coil. At 2 bbl out stop pump and let soak 20 min. Work pipe. Pump a couple more bbl out of coil and soak for 20 Minutes. Work pipe. Go to neutral weight,torque up on HOT, PUH, surge wellhead,work pipe. 08:15 09:21 1.10 9,433 9,094 INTRM1 DRILL FCO XT Pull free into cased hole. Circulate bottoms up for mineral oil and possible gas.Complete circ but no gas. RBIH to 9380'to jet tubulars clean. Open EDC @ 9094 looks like bit plugging offf with motor rubber. 09:21 12:21 3.00 9,094 1,790 INTRM1 DRILL TRIP XT Rock chunks(shale)and motor rubber at surface. Surge choke B, unable to clear. Swap to choke A, reduce pulling speed. 12:21 13:21 1.00 1,790 75 INTRM1 DRILL TRIP XT Continue to surface 13:21 15:51 2.50 75 0 INTRM1 DRILL PULD XT At Surface, PJSM, LD BHA#9, reconfigure BHA componets for dummy whipstock drift. Mill out at 3.79 No Go. **Decision made to plugback this hole and redill hole section. 15:51 19:30 3.65 0 66 INTRM1-DRILL PULD XT PJSM, PU BHA#10, Dummy Whipstock drift 19:30 22:15 2.75 66 9,385 INTRM1 DRILL TRIP XT RIH With BHA#10. Tie in fora+2'. Continue RIH to 9385' 122:15 00:00 1.75 9,385 3,310 INTRM1 DRILL TRIP XT Trip out of the hole. 12/25/2011 / Set 4.5"Ni CIBP,top of plug @ 9365'. Set 4.5"Whip Stock,TOW @ 9348'.TIH with window milling BHA. �/ 00:00 01:00 1.00 3,310 66 INTRM1 DRILL TRIP XT Continue TOOH 01:00 01:15 0.25 66 66 INTRM1 DRILL SFTY XT PJSM Page 12 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 03:00 1.75 66 0 INTRM1 DRILL PULD XT LD BHA#10 03:00 04:15 1.25 0 55 INTRM1 DRILL PULD XT PJSM. PU BHA#11,cast iron bridge plug for 4-1/2"liner 04:15 07:00 2.75 55 9,210 INTRM1 DRILL TRIP XT RIH W/CIBP 07:00 07:06 0.10 9,210 9,245 INTRM1 DRILL DLOG XT Log tie in for+14'to 9259' 07:06 07:24 0.30 9,245 9,376 INTRM1 DRILL TRIP XT RIH to 9385, PUH to 9375.7, PUW=40K. Puts top of plug @ 9374'. Shut EDC,pressure up to 4600 and blow pop off. Come on line and are able to pump through setting tool. Didn't see normal indication of set set plug, but able to set down 4500 lbs. 07:24 08:33 1.15 9,376 7,375 INTRM1 DRILL TRIP XT PUH to 7375'. PT plug to 2000 psi, chart 5 min flat line. Bleed down to 100 negative test-good. POOH keeping hole full 08:33 10:33 2.00 7,375 97 INTRM1 DRILL TRIP XT Trip out 10:33 12:33 2.00 97 86 INTRM1 DRILL PULD XT At surface,perform flow check- good. PJSM, Lay down plug setting tools. P/U Whipstock 12:33 13:03 0.50 86 86 INTRM1 WHPST PULD XT Whipstock in hole, BHI needs system reboot and install database 13:03 16:03 3.00 86 9,244 INTRM1 WHPST TRIP XT Trip in well with whipstock 16:03 16:12 0.15 9,244 9,267 INTRM1 WHPST DLOG XT Log tie in for+3'correction, PUW=44K 16:12 16:30 0.30 9,267 9,260 INTRM1 WHPST TRIP XT Trip in to setting depth, Lightly tag plug @ 9365, PUH to confirm tie in. 16:30 17:15 0.75 9,260 9,364 INTRM1 WHPST DLOG XT Log tie in for no correction,tag top of plug @ 9365'. Plug was supposed to be at 9374'-discover we made tie-in ,� error on plug setting trip. 17:15 17:30 0.25 9,364 9,364 INTRM1 WHPST WPST XT Tag plug @ 9365, PUH 10'. RIH to 9364'. Orient to 150 deg ROHS, \,,,/ pumps on,tool shifted @ 4100 PSI. Set down 4K, PUW=42K. TOWS=9348', BOWS=9364' 17:30 20:00 2.50 9,364 0 INTRM1 WHPST TRIP XT Trip out of well 20:00 22:30 2.50 0 104 INTRM1 WHPST PULD XT Tagged up. No flow test good. PJSM,L/D BHA#12. PU window milling BHA#13. 22:30 00:00 1.50 104 5,623 INTRM1 WHPST TRIP XT TIH 12/26/2011 Dry tagged TOWS @ 9345'.Milled window,drilled to 9371'.Made several reaming passes,window drifted clean. Pulled wiper to swab, no notable shale to surface. 00:00 01:15 1.25 5,623 9,255 INTRM1 WHPST TRIP XT Continue TIH 01:15 01:30 0.25 9,255 9,289 INTRM1 WHPST DLOG XT Tie in fora+4'correction 01:30 02:15 0.75 9,289 9,346 INTRM1 WHPST TRIP XT Pu wt,43k. RIH tag TOWS @ 9345.86. Call town&discuss. Page 13 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 10:15 8.00 9,346 9,351 INTRM1 WHPST MILL XT PUH. Dial in,2.6 BPM @ 3721 PSI, 13.3 ECD. RIH to 9345.1',start time milling see motor work @ 9345.3 and s.. call pinch point 10:15 13:00 2.75 9,351 9,354 INTRM1 WHPST MILL XT Milled down 6'to 9351.3,go to 1 FPH,2.6 BPM @ 3580 PSI, 13.1 \\/ ECD, BHP=4004 13:00 15:45 2.75 9,354 9,359 INTRM1 WHPST MILL XT 9354.3. @ 6 to 9'into window,Go to 64- W2 FPH.2.6 BPM In and out. HP=260, ECD=13.3 I 15:45 19:00 3.25 9,359 9,371 INTRM1 WHPST MILL XT 9359',milling ahead,2.6 BPM BHP=4080,WHP=240 19:00 21:00 2.00 9,371 9,371 INTRM1 WHPST REAM XT 9371', PUH hole make reaming passes.Window clean. Pump 5 lo,5 hi sweeps.get to bit, chase out. 21:00 23:45 2.75 9,371 104 INTRM1 WHPST TRIP XT POOH,chase out to surface. No shale over shakers,mostly metal. 23:45 00:00 0.25 104 110 -INTRM1 WHPST SFTY XT Tagged up.Conduct PJSM. 12/27/2011 Swapped to drilling BHA. Drilled intermediate liner hole from 9351'to 9449' 00:00 02:30 2.50 104 9,327 INTRM1 WHPST TRIP XT Trip back hole to kill well to LD BHA. 02:30 05:30 3.00 9,327 132 INTRM1 WHPST TRIP XT 9327', 12.5 KWF to the bit. PUH per tripping schedule laying in KWF to surface 05:30 08:18 2.80 132 0 INTRM1 WHPST PULD XT 132'at surface,flow check well,crew change, Lay down window milling BHA#13. Mill out @ 3.78 no go, String reamer out @ 3.79 No go. Adjust motor, service injector,check stack 08:18 09:12 0.90 0 70 INTRM1 DRILL PULD XT PJSM, M/U drilling BHA#14, 1.5 degree motor and Bi center with port brazed shut. M/U to coil track, surface test,stab injector on well 09:12 11:42 2.50 70 9,220 INTRM1 DRILL TRIP XT RIH 11:42 11:54 0.20 9,220 9,262 INTRM1 DRILL DLOG XT Log gamma tie in for+3'correction 11:54 12:06 0.20 9,262 9,370 INTRM1 DRILL TRIP XT Trip into above window 12:06 13:12 1.10 9,370 9,370 INTRM1 DRILL CIRC XT Circulate well to new 11.0 PPG Mud, PUW=42K 13:12 13:30 0.30 9,370 9,371 INTRM1 DRILL TRIP XT Good 11 ppg fluid back at surface, trip in to drill, recovered all KWF have 270 BBIs 13:30 18:00 4.50 9,371 9,393 INTRM1 DRILL DRLG XT 9371', Drill Ahead,2.6 BPM@3617 PSI FS, BHP=4090, ECD=13.3 18:00 00:00 6.00 9,393 9,449 INTRM1 DRILL DRLG XT Drilling ahead.2.6 BPM @ 3617 PSI FS, BHP=4110 PSI,WOB=2.8K, ECD= 13.4 12/28/2011 TD intermediate liner section to 9595'. Swap hole to KWF. PU and MU 3-1/2"liner. 00:00 02:00 2.00 9,449 9,469 INTRM1 DRILL DRLG XT Drilling intermediate liner.2.6 BPM @ 3450 PSI FS, BHP=4767 PSI, WOB=2.0K, ECD= 13.4 Page 14 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:45 1.75 9,469 9,520 INTRM1 DRILL DRLG XT Drilling break @ 9469', ROP increased to 12 fph to 40 fph,WOB =2.3K Pumping 15 bbl lo/15 bbl hi viscosity pill down the CT. 03:45 04:30 0.75 9,520 9,155 INTRMI DRILL WPRT XT BHT= 120 deg. Start PUH after the hi vis has exitied the bit. Up wt=43#. Pressure spike at 9380'. PUH to 9271'open EDC. Circulating 3 bpm @ 3300 psi. PUH at 10'fpm to 9155'. No additional cuttings reported with sweep 04:30 05:15 0.75 9,155 9,520 INTRM1 DRILL WPRT XT RIH circ 2.5 bpm @ 2600 psi.Tie in at 9235', no correction. RIH to 9295', close ECD.Cont RIH, RA marker depth=9360',TOWS=9348'. Set down at 9372',work past. 05:15 06:57 1.70 9,520 9,595 INTRM1 DRILL DRLG XT 9520', Drill Ahead,2.6 BPM @ 3430 PSI FS, BHP=4150 06:57 08:51 1.90 9,595 9,595 INTRM1 DRILL WPRT X 9595',Call TD, Recip pipe,sweeps not ready 08:51 09:15 0.40 9,595 9,381 INTRMI DRILL WPRT X Sweeps coming out,Wipe to swab chaseing sweeps 09:15 09:39 0.40 9,381 9,340 INTRM1 DRILL WPRT XT 9381, Overpull, pack off, unable to RIH.Work pipe down. Break free and establish returns,work pipe up through shales and into cased hole 09:39 12:45 3.10 9,340 80 INTRM1 DRILL WPRT X Continue wiper to swab,2.6 BPM EDC Closed,started getting medium sized shales at shaker @ 2200', cleared up @ 800' 12:45 15:30 2.75 80 9,235 INTRM1 DRILL WPRT X At surface, reset counters,Trip back in hole 15:30 15:36 0.10 9,235 9,258 INTRM1 DRILL DLOG X Log tie in for+2', RIH 15:36 15:54 0.30 9,258 9,338 INTRM1 DRILL TRIP X trip in to top of window 15:54 18:40 2.77 9,338 87 INTRMI DRILL TRIP X Trip out of hole laying in 12.5 KWF, PUW=42K, Paint EOP Flags @ _ 9000&8800' 18:40 18:59 0.33 87 87 INTRM1 DRILL TRIP X Close EDC. No flow check, PJSM. 18:59 20:29 1.50 87 0 INTRM1 DRILL PULD X Fill hole, unstab, lay down drilling BHA#14. 20:29 22:29 2.00 0 0 INTRM1 CASING PULD X Prep floor for liner run. PJSM. 22:29 23:59 1.50 0 410 INTRM1 CASING PUTB X PU&MU 3-1/2"liner and BHA#15. 12/29/2011 RIH with 3-1/2"intemediate liner. Unable to reach TD. Liner released downhole.Attempted to fish liner without success. 00:00 00:30 0.50 410 470 INTRM1 CASING PUTB X Continue MU 3-1/2"liner BHA#15. 00:30 01:20 0.84 470 474 INTRM1 CASING PUTB X Test MWD,stab onto well. RIH 4ft, circ out shoe of liner @ 0.25 bpm. 01:20 05:39 4.33 474 9,268 INTRM1 CASING RUNL X RIH with liner at 30 fpm, pumping at 0.25 bpm @ 400 psi. Page 15 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:39 06:15 0.60 9,268 9,396 INTRM1 CASING RUNL X Tie in with EOP flag, +1.5'correction. Up wt=45K#. Crew change out. Continue RIH 20 fpm, 0.25 bpm. 06:15 07:27 1.20 9,396 9,396 INTRM1 CASING RUNL X Set down in tight spot, Hard bottom with clean pickups,Work at slow speeds and different pump rates. 07:27 12:42 5.25 9,396 9,636 INTRMI CASING RUNL XT Pump 15 BBL Liner running pill with beads, Get three BBIs out and let soak.Set down on bottom and bull heads below liner,Work pipe.Try jetting down past tight spot. No good 12:42 15:42 3.00 9,636 492 INTRM1 CASING RUNL XT POOH for FCO Run, PUW=42 15:42 17:13 1.53 492 0 INTRM1 CASING PULD XT At Surface, Flo Check Well, PJSM to lay down liner,pop off to find liner has released down hole Lat down BHA#15. Service injector. 17:13 17:28 0.25 0 48 INTRM1 CASING PULD XT Pick up and make up BHA#16 to fish liner. RIH 17:28 19:58 2.50 48 8,922 INTRM1 CASING TRIP XT RIH to 8900',tie in to gamma+6 ft. Wt check=44K#, Continue RIH 19:58 20:58 1.00 8,922 8,974 INTRM1 CASING FISH XT Set down on fish @ 8974'. Needed 2 attempts to latch on. PU to 65K# (22K#WOB).tried working the liner free several time.Tried circulating fluids, no returns.Several more attempts to free liner while pumping. 20:58 22:58 2.00 8,974 8,974 INTRM1 CASING FISH XT Release from liner, bleed off pump press. Run back in and engage liner. Several attempts to work free. Open EDC,pump 7 bbls of LVT200 down the CT taking returns up the IA. 22:58 23:58 1.00 8,974 8,974 INTRM1 CASING FISH XT 5 bbl of LVT around the CT.Close the EDC.Attemp to pump down the IA to bullhead LVT around the liner, pressures up to 1200 psi after 0.5 bbl and holds pressure.Attempt to work the liner up and down with and witout IA pressure. 12/30/2011 V/ Attempt to fish liner failed.Cut 300'of CT.Test BOPE. 00:00 00:45 0.75 8,974 8,974 INTRM1 CASING FISH XT Continue to attempt to work the liner up and down,with and without IA pressure. Unable to pump any LVT around the liner.After several cycles with the CT,with and without pressure on the IA,the GS released. Unable to latch onto the liner after the release. 00:45 01:45 1.00 8,974 8,970 INTRM1 CASING CIRC XT Pick up 5 ft.Circulate bottom up. 01:45 04:00 2.25 8,970 48 INTRM1 CASING TRIP XT POOH with fishing BHA#16 04:00 04:45 0.75 48 0 INTRMI CASING PULD XT Flow check, PJSM. Lay down BHA #16 04:45 05:30 0.75 0 0 INTRM1 CASING SVRG XT Injector maintenance. Page 16 of 30 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:30 07:45 2.25 0 0 INTRM1 CASING SLPC XT Move injector to the floor. Remove UQC and CTC. Cut 300'of pipe 07:45 10:15 2.50 0 0 INTRM1 CASING SLPC XT PJSM, Boot end of e-line,stab on and perform slack mgmt, Unstab and cut 40'of coil to find wire. Install CTC, Pull test to 40K, 10:15 12:15 2.00 0 0 INTRMI CASING SLPC XT Test wire-good, Head up E-line UQC, PT to 4K 12:15 13:45 1.50 0 0 INTRM1 CASING DISP XT Jetting stack while rolling hole to water, Flush choke lines 13:45 14:00 0.25 0 0 INTRM1 CASING SFTY XT PJSM for BOPE Test 14:00 00:00 10.00 0 0 INTRM1 CASING BOPE XT Start BOPE Test,Witnessed by Jeff h Jones,AOGCC 12/31/2011 / Complete BOPE testing.Attempt to fish liner, no success. Drift liner with slickline for chem cut. 00:00 03:00 3.00 0 0 INTRM1 CASING BOPE XT Continue BOPE test. Started @ 14:00 on 12/30.Witnessed by Jeff Jones,AOGCC 03:00 06:15 3.25 0 78 INTRM1 CASING PULD XT PJSM. Install check valves, circ KWF into CT.MU fishing BHA#17, Hook up to coil and surface test 06:15 08:30 2.25 78 8,930 INTRM1 CASING TRIP XT RIH fishing BHA#17, EDC close, Pumping 1 BPM 08:30 08:45 0.25 8,930 8,947 INTRM1 CASING DLOG XT Log tie in for+4'correction, PUW=43.5 08:45 08:51 0.10 8,947 8,977 INTRM1 CASING TRIP XT Trip to top of liner 08:51 11:45 2.90 8,977 8,977 INTRM1 CASING FISH XT Latch fish on first set downd,Jar fish up, no luck try some down up combos,Jar total of 52 times. No Movement. Pump off fish 11:45 14:00 2.25 8,977 100 INTRM1 CASING TRIP XT Trip out BHA#17 14:00 15:30 1.50 100 0 INTRM1 CASING PULD XT At Surface, Flo check well, PJSM Lay down BHA#17 Fishing tools 15:30 16:00 0.50 0 0 INTRM1 CASING SFTY XT Safety meeting/Job planning meeting with HES Slickline crew 16:00 18:45 2.75 0 30 INTRM1 CASING SLKL XT Rig Up HES Slickline unit to drift stuck liner 18:45 20:00 1.25 30 9,370 INTRM1 CASING SLKL XT RIH with HES Slickline. Runnig bailer for drift and tag. 20:00 20:30 0.50 9,370 30 INTRM1 CASING SLKL XT Hard tag at 9370'(corrected SL measurement). POOH 20:30 21:30 1.00 30 30 INTRM1 CASING SLKL XT SL at surface. Swap out BHA to tag top of liner for depth verification. RIH 21:30 22:00 0.50 30 30 INTRM1 CASING SLKL XT Hard tag at 8962'(corrected SL measurement). Previous CTD liner top depth tag was 8974'(+12'deeper then SL), correct previous SL tag depth inside of liner to 9358'. POOH 22:00 23:00 1.00 30 0 INTRM1 CASING SLKL XT SL at surface. PJSM. Rig down slickline equipment and unit. 23:00 00:00 1.00 0 0 INTRM1 CASING SVRG XT Prep for E-line. Man down drill. General maintenance. 01/01/2012 E-Line hole punch at 9348'. E-line chemical cut at 9347'. E-line chem cut tool string(40 ft),stuck and j released after firing.Top of tools—9302', inside the 3-1/2"liner Page 17 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 INTRM1 CASING SVRG XT General maintenance, charging accumulator bottle. Waiting on SLB, called out at 21:00 on 12/31. 01:00 06:00 5.00 0 0 INTRMI CASING ELNE XT SLB E-line on location. PJSM, rig up. 06:00 10:00 4.00 0 0 INTRM1 CASING ELNE XT Crew change NAD and SLB PJSM Continue rig up 10:00 12:00 2.00 0 0 INTRM1 CASING ELNE XT Rig up complete,start making up E-Line tools 12:00 14:30 2.50 0 9,348 INTRM1 CASING ELNE XT RIH with 2'of perf guns 14:30 15:00 0.50 9,348 9,348 INTRM1 CASING ELNE XT Log CCL/Gamma tie in,Shoot holes in stuck 3-1/2"liner 9348 to 9350 15:00 16:15 1.25 9,348 0 INTRM1 CASING ELNE XT Trip out after perforating pipe 16:15 16:45 0.50 0 0 INTRM1 CASING ELNE XT At surface, Pull lubricator off well and pull tool string to surface,All shots fired 16:45 17:00 0.25 0 0 INTRM1 CASING ELNE XT PJSM,Test safe system, M/U Chemical Cutter 17:00 19:00 2.00 0 9,347 INTRM1 CASING ELNE XT Log CCL/Gamma tie,shot chem cutter at 9347'. 19:00 20:45 1.75 9,347 7,600 INTRM1 CASING ELNE XT PUH with Eline—5'when tool became stuck.Tried to work up and down,could see any jar action. Gradually increased pull weight to a max 3000#(pre SLB)and held weight.Weight broke back suddenly to 500#. POOH, pulling about 400# light and no communication with tools.Assume tool released at weak point. 20:45 22:00 1.25 7,600 300 INTRM1 CASING ELNE XT Eline at 7600', CCL started giving erratic communication while POOH. No gamma communication.Continue POOH 22:00 22:30 0.50 300 0 INTRM1 CASING ELNE XT Eline at 300',stop for PJSM regarding rig down of Eline tools and spent chem cutter. Continue POOH. 22:30 00:00 1.50 0 0 INTRM1 CASING ELNE XT Eline at surface without toolstring, pulled out of rope socket. Rig down and lay down Eline. **Weak point was set for 4095#, approved for 75%of pull, max pull was 3000#when released.** 01/02/2012 Fished cut section of 3-1/2"liner. Ran SL and retreived E-line chemical cutting tool string 00:00 00:30 0.50 0 0 INTRM1 CASING ELNE XT Continue rigging down and kicking out Eline equipment. 00:30 01:45 1.25 0 109 INTRM1 CASING PULD XT PJSM. Prep rig floor for fishing run. Rig up fishing BHA#18 01:45 04:00 2.25 109 8,900 INTRMI CASING TRIP XT RIH with fishing BHA#18 Page 18 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 8,900 8,950 INTRM1 CASING FISH XT Gamma tie in at 8900', +4 correction. PU wt=40K#. Tag top of liner at 8975',sit down 5K#, PU wt=45#, WOB=-3K. Repeat sit down and PU with same depths and weights. PUH 20' 04:30 08:00 3.50 8,950 133 INTRM1 CASING TRIP XT Open EDC. Pump 20 bbl up the IA, POOH at 50 fpm pumping 0.6 bpm @ 600 psi. 08:00 10:30 2.50 133 0 INTRM1 CASING PULD XT At surface,flo check well, PJSM, Unstab Injector, lay down Coil track, Lay down BOT fishing BHA, See TOL 10:30 13:30 3.00 0 0 INTRM1 CASING PULD XT PJSM,Go into lay down liner pull 11-1/2 joints of 3 1/2 Hydril 511 liner. Had to heat Baker-locked joints to back off. Left 46.02' Fish in hole: Shoe,float sub,x/o,one 31.69'joint, &11.24'cut joint,TOF=9348', Recovered 374.47'including deployment sleeve. E-Line string not recovered 13:30 15:30 2.00 0 0 INTRM1 CASING SVRG XT Call out Slickline to fish E-Line String. Clean rig floor minor maint. tasks 15:30 18:15 2.75 0 0 INTRM1 CASING SLKL XT Slick line on location, PJSM spot and rig up to fish E-Line tool string 18:15 19:00 0.75 0 0 INTRM1 CASING SLKL XT RIH to 1600',tools running slow and sticking. POOH to add weight bar. At surface,4"piece of metal(could not identify)wrapped around the bell guide. Remove metal and added weight bar. 19:00 21:00 2.00 0 0 INTRM1 CASING SLKL XT RIH to 7225'unable to pass through liner packer jewelery. POOH. Remove 3.62"bell guide and install a 2.72"mule shoe bell guide. _ 21:00 22:15 1.25 0 9,298 INTRM1 CASING SLKL XT RIH,sit down at 9298'(SL corrected depth). Pick 200#heavier,sit down several time. POOH 200#heavy. 22:15 23:00 0.75 9,298 100 INTRM1 CASING SLKL XT POOH. 23:00 00:00 1.00 100 0 INTRM1 CASING SLKL XT PJSM. PUH to surface, break cap, lift tools to confirm fish is latched. Rig down and kick out SL tools and E-line fish(chem cutter). 01/03/2012 Drifted for whipstock. Set whipstock at setting depth 9331.7'[TOWS 9316.0'];oriented 210-deg ROHS. Proceeded with injector skate change prior to milling window. 00:00 00:30 0.50 0 0 INTRM1 CASING SLKL XT Continue to rig down and kick out SL tools and Eline fish(chem cutter). 00:30 00:42 0.20 INTRM1 WHPST SFTY X PJSM 00:42 02:00 1.30 0 73 INTRM1 WHPST PULD XT Prep rig floor. Pick up and rig up dummy whipstock drift BHA#19 02:00 04:30 2.50 73 9,348 INTRM1 WHPST TRIP XT RIH with whipstock drift,80 fpm,0.3 bpm @ 400 psi. Tie in at 9225', +2 ft correction.Wt check=42K#. RIH, tag at 9348'. Page 19 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 9,348 110 INTRM1 WHPST TRIP XT POOH. Up wt=42K#, 0.6 bpm @ 530 psi. 07:00 08:30 1.50 110 0 INTRM1 WHPST PULD XT At surface, 15 Min No flo test and PJSM, Lay down dummy whipstock, BHA#19 08:30 10:30 2.00 0 84 INTRM1 WHPST PULD XT M/U BHA#20,Whipstock 10:30 14:00 3.50 84 9,230 INTRM1 WHPST TRIP XT RIH with EDC open pumping .3 bpm KWF. 9 14:00 14:30 0.50 9,230 9,316 INTRMI WHPST WPST XT Tie in+1 correction. P/U weight 42K. Close EDC-RIH to 9340' P/U to setting depth of 9331.7'- TOWS 9316'. Set 3200 psi WOB 2.6K.Set down 5K. 14:30 17:12 2.70 9,316 140 INTRM1 WHPST TRIP XT P/U weight 44K-POOH laying in 12.5 ppg KWF. 17:12 17:36 0.40 140 0 INTRM1 WHPST PULD XT Flow check. Conduct PJSM for make-down of tools. Start L/D of BHA#20. 17:36 19:18 1.70 0 0 INTRM1 WHPST PULD XT Rig crew change-out&do valve checklist. Conduct PJSM for night crew for make-down of tools. Finish L/D of BHA#20. 19:18 00:00 4.70 0 INTRM1 WHPST SVRG X Begin injector maintenance. Unstab CT. 01/04/2012 Complete injector head maintenance. Stab 2 3/8"CT, MU CTC(pull test 40K)MU BHI drilling head(psi test ✓ 4000psi). PU/MU/RIH with BHA 21 (3.8"window mill,2.79"string mill,2 7/8"motor.5 AKO)Monitor skate temps while RIH. BHT=112deg 00:00 06:00 6.00 0 0 INTRM1 WHPST SVRG X Continue injector maintenance,skate replacement. 06:00 13:00 7.00 0 0 INTRM1 WHPST SVRG X Crew change-PJSM-install chains and pack off assembly. 13:00 15:00 2.00 0 0 INTRM1 WHPST SVRG X PJSM-Stab pipe,cut 10ft of coil& inspect CT. 15:00 17:30 2.50 0 0 INTRM1 WHPST SVRG X Start re-heading coil connector& installing counters. Pull test CTC 40K. (Good) 17:30 18:00 0.50 0 0 INTRM1 WHPST SFTY X Crew change-PJSM 18:00 19:00 1.00 0 0 INTRM1 WHPST SVRG X Complete BHI drilling head. Pressure test 4000psi. (Good) 19:00 19:15 0.25 0 0 INTRM1 WHPST SFTY XT PJSM 19:15 20:45 1.50 0 0 INTRM1 WHPST PULD XT MU BHA 21. (3.8"window mill,3.79 "string mill, 2 7/8"motor w/.5 AKO 20:45 21:45 1.00 83 3,105 INTRM1 WHPST TRIP XT RIH.3000'temps getting to high. Grease skates.Temps coming back down to normal operating temps. Cont RIH 21:45 22:06 0.35 3,105 3,105 INTRM1 WHPST TRIP XT Tag up on GLM 3105'. 10K. PU orient HS.Cont. PUH, RIH Drift thru GLM, set down 3K @ 3109'pop thru. Cont. RIH BHA length 83'. PUH above 3105'. RBIH 60 LOHS drift thru no issues. NOTE: Need to have 60 LOHS to run thru GLM#1 at 3100'. Page 20 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:06 22:48 0.70 3,105 5,830 INTRM1 WHPST TRIP XT Cont. RIH monitoring skate temps. 22:48 23:48 1.00 5,830 9,250 INTRM1 WHPST TRIP XT Tag on GLM#3 5830'.4K down. PU orient TF 60 LOHS. RIH drift thru _clean.Cont. RIH 23:48 00:00 0.20 9,250 9,250 INTRM1 WHPST DLOG XT Tie in depth-2'correction 01/05/2012 RIH with milling BHA, Dry tag TOWS 9318'. Mill window 9317.8 to 9326.3'(0 Stalls)Mill formation 9327'to 9347'. Backream window. Drift window. POOH following MP schedule. 00:00 01:30 1.50 9,250 9,300 INTRM1 WHPST CIRC XT Displace KWF out of well 01:30 03:00 1.50 9,300 9,318 INTRM1 WHPST CIRC XT Close EDC. RIH dry tag TOWS @ 9318'.2K down DHWOB. Pick up 43K. Online with pumps 2.5 BPM, 2800psi CTP,430 diff, 3800 ann. psi, 17K CTW, 12.4 ECD open choke. Slowly RIH to mill 03:00 04:00 1.00 9,318 9,319 INTRM1 WHPST MILL XT Start milling 9317.8', 150 LOHS toolface. 1.5 FPH.2.5 BPM,460 diff psi, 1001bs DHWOB 04:00 05:00 1.00 9,319 9,320 INTRM1 WHPST MILL XT Cont milling 1.1 FPH,2.5 BPM, 3265 CTP,3.5K WOB, 11K CTW,731 diff psi t)J 05:00 08:00 3.00 9,320 9,322 INTRM1 WHPST MILL XT Cont milling 1.1 FPH,2.5 BPM,3230 CTP,4.2 WOB, 12K CTW 08:00 12:00 4.00 9,322 9,327 INTRM1 WHPST MILL XT Midway point-WOB decrease to 1.8K,2.5 bpm,3000, BHP 3860, ECD 12.6, ROP 1 fph,Start adding Resinex to milling fluid. 12:00 14:00 2.00 9,327 9,332 INTRM1 WHPST MILL XT Full Exit BOW=9326.3'milling formation.Start time milling formation @ 2fph.2.5 bpm,2800psi, BHP 3860, ECD 12.6,WOB.6K,ct weight 13K. 14:00 20:30 6.50 9,332 9,347 INTRMI WHPST MILL XT Mill formation 3-5 fph. 20:30 21:15 0.75 9,347 9,347 INTRM1 WHPST REAM XT Back ream window up/down/up. Looked good. Drift window, pumps off. Looks good.Tag TD 9347'. PUH above window. 21:15 23:45 2.50 9,347 0 INTRMI WHPST TRIP XT Open EDC, POOH following MP schedule pumping 2 BPM. Changeout bladder's on mud pumps while POOH. 23:45 00:00 0.25 0 0 INTRM1 WHPST SFTY XT At surface, PJSM 01/06/2012 Undeploy BHA 21.Service injector head, inspect flapper valves, perform BOPE function test. Deploy BHA 22 (3.75"Bi-center, 1.6 AKO)RIH,drill intermediate lateral 9347'-9446'. 00:00 02:30 2.50 0 0 !INTRM1 WHPST PULD XT Undeploy BHA 21 LD tools. Mills Gauge 3.80 GO, 3.79 NO GO • 02:30 03:15 0.75 0 0 INTRM1 DRILL BOPE XT Inspect flapper valves on UQC, (looked Good)Perform BOPE Function Test, Service injector head. 03:15 04:45 1.50 0 0 INTRM1 DRILL PULD XT Deploy BHA 22. (3.75"bi-center, 1.6 AKO,w/o USR BHA component) 04:45 07:45 3.00 0 9,250 INTRM1 DRILL TRIP XT RIH-tie in-2 ft correction.Close EDC. P/U weight 42K. Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:15 0.50 9,250 9,348 INTRM1 DRILL TRIP XT RIH slowly through window @.2 bpm, 17 fpm,tagged 9327'.Shut down pump, P/U 42K, RIH no pumps slid through. Motor work seen @ 9348' 08:15 12:15 4.00 9,348 9,383 INTRM1 DRILL DRLG XT Start drilling ahead-2.5 bpm, 3300psi, BHP 3890,WOB 1.8K, CT weight 19K, ROP 4 fph.Temp 118 B/U looks like normal shale cuttings. 2.5 bpm, 3400psi, BHP 3880, ROP 10,WOB 1.9K,Ct weight 18K. Normal Shale materials over shaker. 12:15 13:30 1.25 9,383 9,392 INTRM1 DRILL DRLG XT BY-pass choke to blow it out,back to normal-2.5 bpm, 3400, BHP 3890,WOB 2K, ROP 10,CT weight 17K.Temp 116 9392'Weight stacking out with no WOB-P/U weight 42K. Choke B acting up,switch to choke A. Shale looks normal. 13:30 17:30 4.00 9,392 9,416 INTRM1 DRILL DRLG XT Drilling-2.5 bpm,3380,WOB 1.7K, CT weight 18K, ROP 6, BHP 3890. temp 116,choke A. 17:30 18:00 0.50 9,416 9,416 INTRMI DRILL SFTY XT Crew change, PJSM 18:00 21:00 3.00 9,416 9,431 INTRM1 DRILL DRLG XT Drilling-2.5 bpm,3388,WOB 1.7K, CT weight 15K, ROP 4-6, BHP 3900. temp 117,choke A. Flush and inspect choke B. Stem and seat look good. Found 1/2 cup metal shavings. Stay on choke A for consistent pressures. 21:00 00:00 3.00 9,431 9,446 INTRM1 DRILL DRLG XT Drilling-2.5 bpm,3380,WOB 1.7K, CT weight 14K, ROP 4-6, BHP 3820. temp 118, choke A. Mud weight in 10.7ppg heavy.Water back drilling mud to 10.6ppg. DLS 15-16 01/07/2011 — / TD intermediate lateral 9545'. POOH for long wiper to swab valves. RBIH to TOWS,9310'. Displace well to KWF(12.5ppg). POOH. PU/MU/RIH intermediate liner with mill and motor.(3.80"D331, 1.5 deg fixed bend motor, 10 joints Hydrill 3.5"511) 00:00 01:30 1.50 9,446 9,454 INTRM1 DRILL DRLG XT Drilling-2.5 bpm, 3430,WOB 1.7K, CT weight 15K, ROP 4-5, BHP 3930. temp 118, cont. on choke A wide open. DH Bore pressure showing to be erratic 01:30 02:00 0.50 9,454 9,475 INTRM1 DRILL DRLG XT Drilling-2.5 bpm,3400,WOB 1.7K, CT weight 17K, ROP 4-5, BHP 3935. temp 118, Break thru into Klubik 9454'.Slowly Increase ROP. 02:00 03:15 1.25 9,475 9,516 INTRM1 DRILL DRLG XT Drilling-2.5 bpm, 3400,WOB 2.5K, CT weight 15K, ROP 20-30, BHP 3880.temp 118, Mud weight in 10.6ppg 03:15 04:00 0.75 9,516 9,545 INTRM1 DRILL DRLG XT Drilling-2.5 bpm, 3200,WOB 1-2.5K, CT weight 15-17K, ROP 30-50, BHP 3884.temp 120, Mud weight in 10.6ppg, 12.4 ECD Page 22 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:15 0.25 9,545 9,545 INTRM1 DRILL DRLG XT TD lateral 9545',control drill 15 FPH last 5',pumping OH bottoms up to window. 04:15 04:42 0.45 9,545 9,075 INTRM1 DRILL WPRT XT PUH to window. Choke A not operating, Swap to choke B.Cont to PUH, maintaining annular psi. Lower pump rate to 1 BPM thru shales 9450'up to window. Pull heavy, up to 57K picking up thru shales.Cont.to move pipe up hole. Pull thru window minimum rate 43K normal PU weights. Cont.to PUH 20 FPM circulating 2 BPM to circulate cuttings up hole. 04:42 04:48 0.10 9,075 9,075 INTRM1 DRILL WPRT XT Stop at 9075',trap pressure,open EDC. 04:48 06:48 2.00 9,075 2,200 INTRM1 DRILL WPRT XT POOH, pumping 2.5 BPM,following MP schedule 06:48 08:18 1.50 2,200 2,200 INTRM1 DRILL CIRC XT Stop-trap pressure-blow down choke with large shale chunks rolling over shaker.Circ.to clean from B/U from 2200'. Returns cleaned up. Blow down choke. B/U again with more chunks. Clean choke. 08:18 09:18 1.00 2,200 70 INTRM1 DRILL WPRT XT POOH slowly fighting more chunks and choke pressures. Plenty of large chunks over shaker,tag at surface. Blow down choke.Cleaned up 500ft from surface. 09:18 12:18 3.00 70 9,310 INTRM1 DRILL TRIP XT RIH pumping 2 bpm through EDC to TOWS, No shale chunks while RIH. Pump KWF near bottom.Tie in-2ft correction. Pump 20bbl of KWF around. POOH. 12:18 15:18 3.00 9,310 72 INTRM1 DRILL TRIP XT POOH laying in KWF-Flag EOP 8800'. KWF to surface @ 2700' 15:18 15:48 0.50 72 72 INTRM1 DRILL SFTY XT No flow check-PJSM for laying down BHA. 15:48 16:33 0.75 72 0 INTRM1 DRILL PULD XT Lay down BHA-Bit looks good. 16:33 17:00 0.45 0 0 INTRM1 CASING SFTY XT PJSM for P/U Liner assembly-set up rig floor. 17:00 20:30 3.50 0 0 INTRM1 CASING PUTB XT P/U 3.80"D331, 1.5 AKO motor, Baker lock bottom 4 joints, 10 joints Hydrill 3.5"511,deplyment sleeve, 4"GS torq-thru spear,Coiltrak assembly. Inspect flapper valves in UQC-good. 20:30 00:00 3.50 398 6,300 INTRM1 CASING RUNL XT RIH with intermediate liner. 30 FPM, pumping minimum rate. 01/08/2012 Continue to RIH with intermediate liner,Tag at 9371'liner stuck. Pull liner free. Pull out of hole. Lay down ✓ liner. PU/MU/RIH with clean out BHA.Swap hole from KWF(12.5ppg)to drilling fluid(10.6ppg).Attempt to clean out intermediate lateral down to TD 9545'. 00:00 01:15 1.25 6,300 9,200 INTRM1 CASING RUNL XT Cont. RIH with intermediate liner Page 23 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 9,200 9,200 INTRM1 CASING RUNL XT Stop at EOP flag. Correct depth.-3' correction.Orient 210 deg TF. PU for weight check. RIH PUW-47K RIHW-20K 01:30 03:30 2.00 9,358 9,347 INTRM1 CASING RUNL XT RIH thru window 20 FPM,pumping 0.3 BPM, increasing ROP to 45 FPM. Tag up at 9371'. Pumps off, PUH 54K. RIH, online with pumps 0.3 BPM, tag up 9371'. Offline with pumps, PU 60k. Stuck, accidentally released GS off liner. RBIH latch back into liner. Try to circulate 1 BPM,pressure up 6400 psi bore, 3850 ann psi,2000diff psi. Let diff psi bleed down. Diff psi level off at 900psi. Attempt to PU, liner released. RBIH,sting into liner. PUH 64K liner stuck, RIH-10K attempting to pull line free. Multiple attempts trying to pull liner free. Unable to orient, orienter amps up. Line up to pump down backside 500, 800, 1000psi,with 1000psi on CT. Attempt to pull free, Unable to pull free. PU66K, RIH-5K 03:30 04:00 0.50 9,347 9,347 INTRM1 CASING RUNL XT Pressure up backside 500,then 1000psi,0 psi on CT, bleeding off psi (surging)picking up hole 65K. At 1000 psi liner popped free. Cont to PUH. Pull heavy at 9343'. 66K liner stuck. Attempt to surge. Well 1000psi, liner released from GS. RBIH latch into liner 9347'. Pulled liner 26'up hole.Try to circulate while latched into liner. Establish returns, increase rate to.25 BPM. Max rate getting 1 for 1 returns 0.25 BPM. 04:00 06:00 2.00 9,347 9,347 INTRM1 CASING RUNL XT Attempt to PUH with liner.65K Liner stuck. Pressure up backside 1000 psi bleeding off. Pull out of liner. Attempt to latch back into liner. Unable to latch into liner. Orient attempting to latch into liner. 06:00 07:15 1.25 9,290 9,342 INTRM1 CASING RUNL XT Crew change, PJSM. PU weight 46K dry,-2K WOB. Sit down 1.5K. Establish pump rate of 1.2 bpm, good returns. Circ pressure 1800psi, BHP 4000psi. RIH slowly pumping 1.1 bpm,diff pressure 880 psi. RIH slowly milling. 9342'good motor work. WOB 2.1K. Torqued up 9342.27'Started losing returns. Stop pumping-Bleed down&P/U weight 56K. Broke over with 47K drag up to 9326'. Stop. Page 24 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:45 1.50 9,342 9,317 INTRM1 CASING RUNL XT P/U through window slowly-9317' started to pull heavy. Stop, RIH to neutral weight. Try&orient 20 right, then 20 left, no pumps. Still have liner on bottom. Go back to 210 ROHS,try pump 0.2 bpm, returns but torqued up. Stop pump RIH. 9330'-Establish 0.2 bpm,-good returns no torque. Rotate 180 degrees out 45 ROHS. PU slowly through window. Pull heavy @ 9320 stop pumping. PU overpull 9316.8'. Stop coil. Came free.-4K WOB,50K string weight down to 47K. 08:45 11:45 3.00 9,317 410 INTRM1 CASING TRIP XT Continue POOH line up pumping KWF down the backside. Liner is on String weight 46K,-2.5 WOB. 11:45 15:15 3.50 410 0 INTRM1 CASING PULL XT PJSM-flow check-lay down liner BHA 23.Scribe while laying down liner-orientation was 130 degrees out. 340 ROHS/20 LOHS. Bit& GS looked good. Inspected X-over threads-good shape. 15:15 17:15 2.00 0 0 INTRM1 CASING CIRC XT Clean up rig floor,flush BOP's, choke's and stack.Service Injector& reel. 17:15 17:30 0.25 0 0 INTRM1 CASING SFTY XT PJSM 17:30 18:15 0.75 0 0 INTRM1 CASING PULD XT PU/MU Clean out BHA#24 18:15 20:45 2.50 70 9,200 INTRM1 CASING TRIP XT RIH 20:45 21:00 0.25 9,200 9,200 INTRM1 CASING DLOG XT Tie in depth-2'correction 21:00 21:15 0.25 9,200 9,200 INTRM1 CASING CIRC XT Circulate recording pump rates and pressures 1.00 BPM,4059 ann psi,4290 bore psi, 1214 CTP,224 diff psi 1.25 BPM,4094 ann psi,4380 bore psi, 1550 CTP,286 diff psi 1.50 BPM,4131 ann psi,4485 bore psi, 1885 CTP, 348 diff psi 1.75 BPM,4165 ann psi,4540 bpre psi,2310 CTP,419 diff psi 21:15 21:45 0.50 9,200 9,346 INTRM1 CASING FCO XT RIH thru window set down 6K DHWOB. 0.3 BPM, pop thru window. Cont to RIH,stackout 9346'. Concerns of hole cleaning while performing cleanout down to TD, lifting cuttings,etc. 21:45 23:00 1.25 9,346 9,300 INTRM1 CASING CIRC XT PU into cased hole.Open EDC. Swap hole over to milling fuild 10.6 PP9• Page 25 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:45 0.75 9,300 9,373 INTRM1 CASING FCO XT Close EDC, RIH to clean out intermediate. 9321'set down 4.8K DHWOB. Pop thru. RIH 2.3 BPM, 3880 BHP,2800 CTP,389 diff. Set down 9345',600 diff psi, mill off cont. RIH. 1-2 FPM. looking good. 23:45 00:00 0.25 9,373 9,373 INTRM1 CASING FCO XT Stall 9373', DHWOB increase to 10K instantly. Try to PU.66K Stuck. Continue to work pipe. Unable to pump down CT, packed off. Pump down backside 1000psi and surge well bleeding off rapidly trying to pull free.Stuck. 01/09/2012 Attempt to clean out intermediate lateral to TD 9545'. BHA become stuck at 9373'bit depth. Multilple attempts to free BHA, unsuccessful. Release off BHA. POOH. PU fishing BHA. Bi-Directional Hip-Tripper,w/ 3"GS spear. RIH. Estimated top of fish-9319'. 00:00 00:15 0.25 9,373 9,373 INTRM1 CASING FCO XT Let annular psi and bore psi equalize.Try to pull free. Stuck. Load mineral oil into pits. 00:15 00:30 0.25 9,373 9,373 INTRM1 CASING CIRC XT Pressure up backside 1200psi surging well bleeding off trying to pull free. Stuck 00:30 02:15 1.75 9,373 9,373 INTRM1 CASING CIRC XT Pump down CT to establish returns. Establish returns 1-for-1 at 0.3 in, 0.3 out. Pump mineral oil down CT. 02:15 03:00 0.75 9,373 9,373 INTRM1 CASING CIRC XT Mineral oil around BHA. pump 3 bbl, shut down let soak. 03:00 03:15 0.25 9,373 9,373 INTRM1 CASING CIRC XT PU try to pull free.65K stuck. Line up to pump down backside. Pressure up 1200psi. Surge well bleeding down,CT in tension 60K. Stuck,attempt to pull free. Keep CT pressure to minimum. (coil life management).Orient no problem 330 deg around the dial, left and right 03:15 04:00 0.75 9,373 9,373 INTRM1 CASING CIRC XT Pump another 3 bbl and let soak 20min. 8 bbl of mineral oil left in CT. After soak PU try to pull free.65K, stuck. Pump down backside 1000 psi surge well multiple times. RIH 10K WOB, PU-19K WOB. 65K max surface pull weight.WOB limited with tool operational imits. Placement of EDC is in window,circ ports on tray. Fish neck at 9321.8 assuming mill at 9373.8. 04:00 04:30 0.50 9,373 9,373 INTRM1 CASING CIRC XT Go to neutral weight,pump 4 brls mineral oil, let soak 20min,try to pull free.surging well.stuck.cont.to pull. 04:30 05:00 0.50 9,373 9,373 INTRM1 CASING CIRC XT Pump last 4 bbl mineral oil out CT. Choke well back increasing BHP. Pump down down backside 1700psi, surge well. Still stuck. 05:00 05:30 0.50 9,373 9,373 INTRM1 CASING CIRC XT Circulate down CT 1.25 BPM in, .5 out, Work pipe, Stuck Page 26 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 9,373 9,373 INTRM1 CASING CIRC XT Crew change 06:00 10:00 4.00 9,373 9,371 INTRM1 CASING CIRC XT Able to establish circ rate of 0.7 bpm. 1:1 returns and gradually getting better. Cycle pipe a few times with no luck. Pumping 1.2 bpm 1:1 returns. Continue circ bottoms up. Discussion with town to pump Lo/High sweep 25 bbls&try again. 1 hour to mix product. ump 50 bbls-sweeps coming around. Max. P/U weight 67K WOB- 21 K,9364'. RIH,max sit down 9k WOB. No movement-12 attempts while pumping.Total life cycles in spot 22%. 10:00 10:15 0.25 9,371 9,319 INTRM1 CASING CIRC XT No movement-Neutral weight&diff pressure. Function EDC-Release from tool.Top Fish 9319' P/U weight 52K broke over to 44K. POOH holding MPD by choke pressure. Monitor CT string while POOH in case of pin hole. 10:15 13:15 3.00 9,319 26 INTRM1 CASING TRIP XT POOH following MPD using choke pressure pumping 2 bpm. Lots& lots of smaller shale chunks rolling over the shakers and plugging the choke. Stop Moving pipe and circ B/U until it cleans up from 800'. Slowly move CT up hole while cleaning. RIH to 800'again,cleaned up&POOH. 13:15 15:00 1.75 26 0 INTRM1 CASING PULD XT PJSM-Close swab valves, Hold 600 psi on MP line. Flush stack&choke manifolds, more shale over the shakers.Shut down. Pop off well and lay down BHA. **Bleed port screw in the Lower Quick test sub was missing.The plug is roughly 3/8"in size&would be the reason for ciculation on bottom. Port was flow cut.** Time of plug backing out of tool is unknown at this time. 15:00 16:30 1.50 0 60 INTRM1 CASING PULD XT PJSM for deploying BHA#25 with 3"GS, Bi-Di Hipp tripper&Coiltrack assembly. 16:30 19:30 3.00 60 9,245 INTRM1 CASING TRIP XT Rlh with EDC open pumping 1.5 bpm.-stop at 1000'ft and blow down choke. RIH slowly&watch for shale returns. 19:30 19:36 0.10 9,245 9,245 INTRM1 CASING DLOG XT Tie in depth-2'correction, record up and down weights. 18K RIHW.42K PUW Page 27 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:36 20:02 0.44 9,245 9,322 INTRM1 CASING FISH XT Closed EDC. RIH w/o pumps attempt to latch into fish. Tag 9322'. 4.7K DHWOB. PU see if fish latched. Fished latched 55K PUW, -7K WOB. RIH to neutral. PUH 1K DHWOB. Online with pumps in tension, attempting to find sweet spot for hip-tripper. 1.3 BPM,3K WOB, 31K CTW. 3550 CTP, 20:02 20:32 0.50 9,322 9,322 INTRM1 CASING FISH XT Confirm Hip-tripper hitting. Can feel the vibrations on the pipe, PU slowly to 50K,weight drop off 46K,showing +10K WOB. WOB dropped off+2K. WOB should be reading neg. weights. Contintue to PUH to 9263'. assuming fish on, PU above window. 46K PUW. no pumps. RIH tag 9320'. Fish possibly moved up hole 2'. GS prematurely released off fish. 20:32 21:02 0.50 9,322 9,322 INTRM1 CASING FISH XT Confirmed latched into fish 60K PUW, 13K WOB. Slack off-5K WOB,44K CTW,online 1.3 BPM, 3700 CTP, 190 WHP, Hipp Tripper working. Vibrations. over pull 21K WOB. No progress. 21:02 21:32 0.50 9,322 9,322 INTRM1 CASING FISH XT RIH,set down 2K WOB,attempt to hip tripp down 1.25BPM.Stall. PU. RIH set down 2K WOB, .9 BPM, hip tripper working. No progress 21:32 21:47 0.25 9,322 9,322 INTRM1 CASING DLOG XT Release off fish, PUH to tie in depth. +2'correction,so didn't move fish after all. RBIH 21:47 22:02 0.25 9,322 9,322 INTRM1 CASING FISH XT Tag 9322'. Confirm latched in. Hip i trip up 1.3 BPM,-3K WOB,41K CTW, Hip tripper not working,worn out as per BOT rep. 22:02 22:17 0.25 9,322 9,322 INTRM1 CASING FISH XT Line to pump down backside, psi up 1200spi,surging well attempt to pull free.65K PUW. 22:17 23:17 1.00 9,322 9,322 INTRM1 CASING CIRC XT Release off fish. Kill well with 12.5 ppg K-formate. 23:17 23:59 0.71 9,322 INTRM1 CASING TRIP XT POOH 01/10/2012 Hip-tripper run was not successful, PU fishing assembly with jars and accelerator,jar up and down with no movement of fish. Circulate formate brine out of well. 00:00 02:00 2.00 0 0 INTRM1 CASING TRIP XT Cont. POOH 02:00 02:15 0.25 0 0 INTRM1 CASING SFTY XT At surface, monitor well for flow. PJSM 02:15 03:30 1.25 0 0 INTRM1 CASING PULD XT LD BHA,service inj .head 03:30 06:00 2.50 0 0 INTRM1 CASING SLPC XT Prepare to pump slack forward out of CT. Make up Baker external coil connector. Swap to seawater. Tried pumping out against closed swab valve but stiff cable would not move any further than the top of swab. 21ft of cable cut. Page 28 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 INTRM1 CASING SLPC XT Crew change-With KWF open swab valves and pump slack out down the well. Pump slack out, hear cable moving out. Stop moving,surge a few times. Pop off and recover cable. 205ft cut off+21 =226 ft total. Calculate remaining cable slack in reel=52 ft. 08:00 09:30 1.50 0 INTRM1 CASING SLPC XT Close swabs-set up to pump 7/8" ball down CT string into BHA. Put jetting nozzle on coil.Shut inner reel valve and install ball, pressure up to 1000psi,open valve-heard ball launch. Pump 40 bbls and watch for pressure build up. Pumping 2 bpm @ 1600 circ pressure. 09:30 10:30 1.00 0 0 INTRM1 CASING SLPC XT Ball pumped around,80 bbl pumped. Thought to have heard ball drop into nozzle at 51 bbl but never saw pressure increase. Pop off to check for ball. Ball in nozzle. 10:30 10:45 0.25 0 0 INTRM1 CASING SFTY XT PJSM 10:45 11:45 1.00 104 9,323 INTRM1 CASING PULD XT PU dumb-iron fishing BHA#26(2 jnts 2-3/8"PH6,dual flapper, accelerator, 3 wt. bars,jars, disconnect sun for 3/4"ball, rupture disc, 3"hyd.GS Spear) 11:45 14:30 2.75 9,323 9,323 INTRM1 CASING TRIP XT RIH 14:30 14:45 0.25 9,323 9,323 INTRM1 CASING FISH XT Latch fish 9323'with no problem. PUH 70K Jarring.6 licks.Gripper blocks slipping. 14:45 15:15 0.50 9,323 9,323 INTRM1 CASING SVRG XT Release off fish. PUH to clean pipe and gripper block from oil 15:15 16:00 0.75 9,323 9,323 INTRM1 CASING FISH XT RBIH to latch into fish 9323'. Jar on fish 28 down, 1 down.74K PUW to 9312'. When jar hitting,weight drop off to 64K. PUH back to 72K after jar hits. 16:00 17:15 1.25 9,323 9,323 INTRM1 CASING FISH XT Pressure up backside to 1000psi 2000psi.Jar on fish up down with pressure on well. Surging well, bleeding off WH psi.when jar hits to try to get something moving. No success. Total jars hit 51 up 20 down 17:15 20:15 3.00 9,323 0 INTRM1 CASING TRIP XT Make decision to halt fishing ops. Release off fish, POOH.Total length of fish left in hole 51.96'. 3"GS neck looking up. 20:15 20:36 0.35 0 0 INTRM1 CASING SFTY XT PJSM for laying down BHA 20:36 21:36 1.00 0 0 INTRM1 CASING PULD XT Lay down fishing BHA 21:36 22:12 0.60 0 0 DEMOB WELLPF PULD P MU jetting nozzle BHA Page 29 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:12 00:00 1.80 0 DEMOB WELLPF TRIP P RIH 01/11/2012 FP well, pump corrosion inhibitor through surface equipment and CT,set BPV, blow down CT with N2 and change reels, Continue with RD operations 00:00 00:42 0.70 7,000 9,300 DEMOB WELLPF TRIP P Continue to RIH 00:42 04:42 4.00 9,300 2,000 DEMOB WELLPF DISP P Displace formate from well with 11.1 ppg NaCI/NaBr brine with corrosion inhibitor 04:42 07:12 2.50 2,000 0 DEMOB WELLPF FRZP P MIRU LRS and FP well with diesel from 2000'to surface 07:12 11:42 4.50 0 0 DEMOB WHDBO CIRC P At surface, Flush BOP's and rig. Pump inhibitor thru CT and rig iron 11:42 12:42 1.00 0 0 DEMOB WHDBO NUND P Set BPV 12:42 13:12 0.50 0 0 DEMOB WHDBO CTOP P Blow down CT and rig with N2 13:12 14:12 1.00 0 0 DEMOB WHDBO CTOP P Allow CT to bleed down, remove counters 14:12 15:12 1.00 0 0 DEMOB WHDBO CTOP P Unstab 2-3/8"CT. 15:12 00:00 8.80 0 DEMOB WHDBO CTOP P RD reel,Change out reels, continue swaping equipment from 2-3/8"to 2" 01/12/2012 Prepare to move to 3H-34 00:00 06:00 6.00 DEMOB WHDBO CTOP P Continue with conversio of equipment to 2"and rig down operations. Prepare to move rig to 3H-34 ***Rig Release*** Page 30 of 30 • Letter of Transmittal rI BAKER Date: January 0 12 2 12 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-08BPB1 2K-08BPB2 ..kk-152- 2K-08BPB3 .'4 ,' SCANNEDiR (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files RECEIVED JAN 17 2012 AOGCC Note: Please feel free to send us an email in place of return mail. 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'a C C.) 0 m Q) C V Y O '' ` d c w <0 co O d d U N v CO a) NI h CO m a .0 C U d y et >, R N v CO CV CO CO c n Om i" = N CC 'r. m V m O 1` M cO ren- m O 0 N >❑ 'C Z r) v_ v v_ to to to to to V 0 J F- 2 2 h ❑ W to <o co to co q co ai 0 1 + C . 0 V COr_ N CO CD VCV V O? 0) N- 0 to co V O h 6 C) O to h O) C) �'T CNO m m m m m 1- N N- N- Z + i( € N N N CO so N n O m 0 V C) M co N_ m h N m m h N O V CO n O a) N C) m CO C N N Ci= co co O a) O O O O O 0 to to to to to .0 to m com o CV 01 el O) U) m 0 c0 tin m N. CO O 1 CI N CI m m N W C O O U >= 0 0 0. 0 0 — - - ca 0 C cri co m m m m co m <a m R o l6 _ Q D -D (n0, tmn OO) N CD O N- cocC0') y/� `t _n scr,> d La co in Q`—• co N N N N N N CO N N iCO -C rY N ) a.- O ` ` •O U CO CO CO C N 0 0 0 0 uw) c0] 00 0 COO tin O n! N N CmC 3 � YYY E - CCotC CD 0C') O 0 a O U Y Y N N N M OV ,- O O V LO O Off) CO N Csi VI N O N O m 0 0 O_ O to O N to ca f.1 0 C > 2= N- co co co a V N- to to N N OO. _ a 0 ai m m m co- ai O ai ai ai 0 U £ o :? ri m a) e' c°) a �n33o Cl) Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 02, 2012 10:22 AM Q( 1 / To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: 2K-08A and 2K-08B (PTD 211-049 and 211-152) Gary, We (Steve, Dave and myself) sat down and discussed the reporting dilemma regarding 2K-08 and have come to a final decision: 2K-08A needs a 407 report with it P &A 'd as a final status. (As soon it was sidetracked with CTD for the 2k-08B it was abandoned technically). This closes out this PTD . 2K-08B needs a 407 reporting it as suspended. You have all the drilling reports/directional to us already so just need a redone 407 page. There will be PB1, PB2 and the final failed attempt would be called 2K- 08BPB3 as you have done already. The two other PTDs (2K-08BL1 and 2K-08BL1-01) should be withdrawn (can be done by an email request) since they will never be drilled. When you decide to reenter the well the next wellbore will be 2K- 08C and at that time 2K-08B will be closed out by P &A ing it. I hope this makes sense ... please call me with any questions. This was an unusual well sequence so I apologize for the inconsistency on our part. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/2/2012 S. 0 N E C O cu Y a c m O H o f- O O -4 a '++ n Q o J O >, • LU -6 m Q m +-. + , ,- mp V O L o 0 0 a O C "O a (n co i CO N f6 (B H ai D- n3 4) m m t - ❑ E O O O o H O C -c = O O J :? J w m o O (0 -0 _C) N coin co n N N N N W 0 o >' � N � CO W Z W o)- a)'= a) -0 V re C 3 W c F- W Q W •X C N J S cc W = d m a.. I I • m - c M O Q1 � -co' ❑ _ m 1_,8)e-, N1 76 O 7) O (..) ,:\ �[ n.0 3 <° n M n n O d o o E a N rn _ m L ++ N D s0 3 p 0 I co J (3) N CO O) in N QO 1 I c'> 3 a V ilk r OU: m L I •'! o0o rn U ca. o _y111111111 N H (J) Cal L I I!; I f0 (h. O NO❑ o s [� intcsi co N Cl0 ao CD U-) c'_- v n v 3 E _n a co m m_ i o \ N- \ s Y ❑ m co c') v 3o O NH • RFCEIVED J.G.Eller CTD Engineer Drilling&Wells JAN 3 0 71112 P.O.Box 100360 NIPV �* Anchorage,AK 99510-0360 ConocoIIiiIIips Alas.< .. ^ Cons. Commission Phone: 907-263-4172 ,:.:7,'_',`:"; January 16, 2012 AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Status of Well KRU 2K-08A Dear Commissioner: This is to inform the AOGCC of our cessation of drilling operations on KRU 2K-08B (#211-152). We were unsuccessful in getting 3W liner installed during three sidetrack attempts (i.e. 2K-08BPB1, 2K-08BPB2, & 2K-08BPB3). Without completing the 2K-08B sidetrack we were unable to drill the 2K-08BL1 or 2K-08BL1-01 laterals (#211-153 and#211-154, respectively). 140 We are still considering our options and forward plans, but in the meantime we are submitting a 10-164 for the suspension of 2K-08A. The proper well name continues to be 2K-08A since no sidetrack or recompletion was accomplished. As per e-mail communication with AOGCC Engineer Guy Schwartz, the well is adequately secured until we agree on a plan forward. We discussed submitting a 10-407 to suspend the well, but without a recompletion it seemed more appropriate to submit a 10-404 instead. If you have any questions, please feel free to call me at anytime. Sincer ly, ��L,og$ 8\___, J. Ga r CTD Engineer CPAI Drilling JGE/skad Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 03, 2012 1:38 PM To: 'Eller, J Gary'; 'Gandra, Sachin'; Nabors CDR2 Company Man; Nabors CDR2 MWD Engineer; Nabors CDR2 Directional Driller Cc: Crews, Jennifer R Subject: RE: Rename Previous Lateral Thanks Gary... tough going on this one. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Saturday, December 31, 2011 5:34 PM To: 'Gandra, Sachin'; Nabors CDR2 Company Man; Nabors CDR2 MWD Engineer; Nabors CDR2 Directional Driller Cc: Crews, Jennifer R; Schwartz, Guy L(DOA) Subject: Rename Previous Lateral Folks-This last lateral that we drilled and stuck casing in will need to be renamed 2K-08B-PB2. It was drilled from 9345' -9595' MD. We will not set a separate plug to isolate it since it is entirely packed off and we have no communication to the Kuparuk sands. The API number will be 50-103-20111-74. The new lateral that we are planning from 9315' MD will be 2K-08B. Jim- Please forward to the AOGCC Slope Inspector. Guy- I will follow up with a schematic diagram on Tuesday. This is pretty much a repeat of the last plugback except that it has 3-1/2" liner stuck partially in it. Please let me know if you have any questions. -Gary 1/3/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Eller,J Gary[J.Gary.Eller@conocophillips.com] Sent: Tuesday, December 27,2011 10:57 AM To: Schwartz, Guy L(DOA) Subject: RE: 2K-08A( PTD 211-152) Attachments: 2K-08B-PB1 CTD schematic 12-27-11.pdf Guy—As we discussed, this is the 4-1/8" hole section that we had to plug back due to collapsing shales. We set a CIBP in the 4-1/2" liner at 9365'to isolate, and cut a new window at 9346'. The plugback will be named 2K-08B-PB1. Please call if we need to discuss. Schematic attached. -Gary From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, December 26, 2011 10:34 AM To: Eller,J Gary Subject: [EXTERNAL]2K-08A ( PTD 211-152) Gary, Can you send me a well sketch showing what you are doing? Is this the 4.125" section that was to be cemented? Regards. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller,J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Saturday, December 24, 2011 11:20 AM To: Nabors CDR2 Company Man Cc: Gantt, Lamar L; Venhaus, Dan E; 'Gandra, Sachin'; Schwartz, Guy L(DOA); Nabors CDR2 MWD Engineer; Long, Jill W Subject: Plan Forward Jim, Sid—Below is the plan forward for 2K-08B. The window and borehole that we have cut(9419'— 9780' MD)and plan to abandon will be designated 2K-08B-PB1. We had to abandon this hole section due to collapsing shales. Please forward this notification to the AOGCC Slope Inspectors. 1. POOH with existing BHA. 2. PU dummy assembly. Drift to 9385'. 3. PU CIBP for 4-1/2", 12.6 ppf liner. Set CIBP at 9374' MD to isolate 2K-08B-PB1. Pressure test CIBP. 4. PU monobore WS. Tentative plan is to set at 9355' MD at 150 deg ROHS. Sachin is still working that plan though so keep this as tentative. 5. Mill window. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 1/3/2012 4 mib SD U N C) i N in r a N N Q1 r- in (O V V O O el O N Q O O (3 Cs./ if) - C o C N ^ N O ~a O -p c0 Ji J 1— Q) cv CO O m O Y CO O -_ N- t0 0) O N • O p °- C N N Y mN N - N O) Q.j W N N [O f0 �, i6 [O p V rn a) cern -- rn 0 op X - 0 m o N a) Lo c h is rin J Lo - 3 O) N J Y ti p O) N N co 4t co - co p ` Z o m �0 s ri N m CO M co N CD c" X w U p O Y co OO O C '` m O) O N TD_ o a = jrJLL o C U m O N O Cl N N - Q _ 'O N m C 5 \ IC7 V E o v 0 X V � = , CCOOJtLw Ii •Y O d W On O N -o O o ' � 4.4C O p C_ I J ON) p Y O Lo Na 0 • a I r M T 06 \ \ �o (h J CD Ilf co O - ao •CL iIIIIIuIUuUu!u ILIIci o N(3.) I ''1I111IIIIII,//111%kih. 191 I ,. I �` f6 -C92 O) Q d. .� N O O M N CO = In 3 L., . OD a O in o O o J 2 O N co Q O co O 4t 0 Xt0 C O 7 4i R O V O c 00 p Y \ d N m � M2 N � (.0 .1. N m E o macO -N- �N L_m N C- O m (D O) N- \ N v 3 U V 3 N a V 1,.. Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, December 01, 2011 2:07 PM To: 'Eller, J Gary' Cc: Gantt, Lamar L Subject: RE: Change in Casing Program for 2K-08B (PTD 211-152) Gary, Thanks for the information. The change to the approved PTD is minimal and this email notification is sufficient to document it for the record. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:].Gary.Eller@conocophillips.com] Sent: Thursday, December 01, 2011 1:34 PM To: Schwartz, Guy L(DOA) Cc: Gantt, Lamar L Subject: Change in Casing Program for 2K-08B Guy—I wanted to let you know that we'll be making a slight change in the casing program for well KRU 2K-08B. The PTD stated that we would cement 3-1/4", 6.6 ppf, L-80, TC-II liner from 9200' to 9780'. We'll instead be running 3-1/2", 9.3 ppf, L-80, Hydril 511 liner. The depths and cement volumes are unchanged, as is the hole diameter. This increase in liner diameter will allow us to mill a 2.80"window for the 2K-08BL1 lateral instead of a 2.74"window. Please call if we need to discuss. Thanks. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 12/1/2011 • • � dC-M A - o SEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-08B ConocoPhillips Alaska, Inc. Permit No: 211-152 Surface Location: 121' FSL, 94' FEL, SEC. 2, T1ON, R8E, UM Bottomhole Location: 940' FSL, 1677' FEL, SEC. 3, T1ON, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Danie " . Seamount, Jr. Chair Yd Cit/ . DATED this day of November, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RE STATE OF ALASKA '"" I , ? ALASKA OIL AND GAS CONSERVATION COMMISSION 'WAi '1 I 20111 PERMIT TO DRILL ploy a ii & Gas na�a0 Coi��m. -,_ 20 AAC 25.005 xen la.Type of Work: , 1b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone E' lc.Specify if welPliiii cki j: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 - 2K-08B 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:9780' ' TVDSS: 6079' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 121'FSL,94'FEL,Sec.2,T1ON,RO8E,UM / ADL 25588,25589 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 930'FSL, 1350'FEL,Sec.3,T1ON, RO8E,UM 2674,2675 12/15/2011 Total Depth: 9.Acres in Property: 14.Distance to 940'FSL, 1677'FEL,Sec.3,T1ON,RO8E,UM 2560 Nearest Property: >15000' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 146.5 feet 15.Distance to Nearest Well Open Surface:x- 498310 • y- 5938425• Zone- 4 GL Elevation above MSLa(3 7 �1t / . /Same Pool: 2K-13A,1700' 16.Deviated wells: Kickoff depth: 9425 - ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 72' deg Downhole:4492 psig I Surface:3875 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade • Coupling Length MD TVDSS MD TVDSS (including stage data) II' 4.125" 3.25" 6.6# L-80 TC-II 580' 9200' 5846' 9780' 6079' 7 bbls Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 9441' 6098' 7452' 9441' 6098' none Casing Length Size Cement Volume MD TVD Conductor/Structural 74' 16" 115' 115' Surface 3729' 9.625" 2133 sx AS III,595 sx CI G 3770' 2905' Intermediate Production 7393' 7" 230 sx Class G 7434' 5227' Liner 2222' 4.5" 35 bbls Class G 9441' 6098' Perforation Depth MD(ft): Perforation Depth TVD(ft): none none 20.Attachments: Property Plat❑ BOP Sketch o Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements LI 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Gary Eller @ 263-4172 i Printed Name L.'''Gantt Title CTD Engineering Supervisor Signature , Phon 263-4021 Date i tl!i/l/ Commission Use Only Permit to Drill / / API Number: // ) Permit Appr val See cover letter Number: 2-I ( 6 ,S-2-- 50/ 32i)/l I -ti L–W Date: 1, 1` for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalb m ane,gas hydrates,or gas contained in shales: d -#4/506 psi," do t /es f Samples req'd: Yes ❑ No Mud log req'd: Yes El No [/ Other: AL-2$Gb ps p" //"t1,,�w(�„ 7. -..5„.._ cH2S m3asures: Yes [Z] No El 144,..-r% svy req'd: Yes [J� No CILAIIII , . 144,..-r% APPROVED BY THE COMMISSION I , / DATE:�rlll♦� i j. ,COMMISSIONE'£ Form 10-401 (Revised 7/2009) This permit is valid for. mbrtthi fro theidate'of'approval(20 AAC 25.005(g)) Submitubi in Duplicate qr!_ I /f 2 �� - `�/ice/ I�1'D ConocoPhillips p Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NOV 17 2011 November 16, 2011 Alaska Oil &Gas Cons.Commission Anchorage Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for three coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-08A(PTD#211-049) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill one cased and cemented sidetrack and two producing A-sand laterals: 2K-08B, 2K-08BL1, and 2K-08BL1-01. Work is scheduled to begin in December 2011. Also included is the sundry application for abandoning the cased portion of 2K-08A below the proposed sidetrack point of 2K-08B. ConocoPhillips requests a variance from the plugging requirements of 20 AAC 25.112(c)(1). There are no perforations in 2K-08A nor does the proposed plugged interval penetrate any V permeable formations, so the proposal meets the overall objective of preventing migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2K-08B, 2K-08BL1, &2K-08BL1-01 — Proposed & Current Wellbore Schematic — BOP Schematic for'bighole' CTD operations and running 3W liner — BOP Schematic for'slimhole' CTD operations and running 2%" liner — Drilling Program Summary — Directional Plans — 10-403 application for plugging the existing 2K-08A wellbore If you have any questions or require additional information please contact me at my office 907-263-4172. vs,s\Sincerely, Gary Ell ConocoPhi ips Alaska Coiled Tubing Drilling Engineer KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling Summary of Operations: Well KRU 2K-08A is a suspended well equipped with 4'/s"tubing and 4%2"production liner. In June 2011, it was TD'd and cased in the Kalubik shale short of the originally targeted Kuparuk C and A sands. A CTD sidetrack out of the 4'/2"liner will be drilled and cased across the Kuparuk C and A sands'Two A-sand CTD horizontal laterals will then exit this cased section and be drilled west to increase reservoir exposure. Initially the BOPE for Nabors CDR2-AC will be equipped for`bighole' CTD operations(i.e. 3"BHA). Our first operation will be to drill cement out of the 4'/2"shoe track from 9348' to 9440' MD. The 2K-08B sidetrack will ultimately exit the 4%2" liner at 9425' MD from a mechanical whipstock,rendering the cased / interval below 9425' effectively abandoned in 2K-08A. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to abandon 2K-08A in this manner. After setting the whipstock and milling a window in the 4%"liner,we will drill through the Kalubik shale and the C-sand into the A-sand with a 41/4"bi-center bit to a depth of 9780' MD. We will then run 580' of 31/4", 6.6 ppf,L-80 liner with TC-II connections from 9200' to 9780'. The 31/4"liner will be cemented in place with 7 bbl of 15.8 ppg cement,which will isolate the Kuparuk sands and the Kalubik shale behind pipe. V After reconfiguring our BOPE for slimhole operations(i.e.2%"BHA),we will set a whipstock in the 31/4"liner at 9650' MD and then make a window exit at that depth. The 2K-08BL1 lateral will be drilled with a 3"bi- center bit targeting the A4 sand west of 2K-08B with a 2920' lateral. The lateral will be completed with 2%" slotted liner to the TD of 12,570' MD with an aluminum billet at 10,100' MD. r The 2K-08BL1-01 lateral will kick off from the aluminum billet at 10,100' MD and will likewise target the A4 sand west of 2K-08B well with a 2045' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,145' MD with the liner top inside the 31/4" liner at 9640' MD. After completing the 2K-08BL1-01 lateral, as a contingency we will possibly run a 31/4"x 4'/2" liner-top packer at 9200' to provide further isolation to the C-sand formation that is behind the 31/4"cemented liner. The decision to run a liner-top packer will be based upon the thickness and reservoir quality that we find in the C- sand as well as success of the 31/4"liner cement job. Drilling Program - 20 AAC 25.005(c)(13) Pre-CTD Work 1. Positive pressure and drawdown tests on master valve& swab valve 2. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coiled tubing. NU 7-1/16"BOPE,test. BOPE will be configured for `bighole' CTD operations. Pc�r 2. 2K-08B Sidetrack(Intermediate Hole Section) a. Drill out the 41/2"shoe track to a depth of 9440'. b. Set whipstock in 41/2"liner at 9425' MD c. Mill 3.80"window with high-side orientation at 9425'MD d. Drill 3.70"x 41/8"bi-center lateral to TD of 9780' MD ✓ e. Lay in over-balanced fluid prior to running liner f. Run 31/4"blank liner with TC-II connections from TD up to 9200'inside the 41/2" liner --fty g. Cement 31/4"liner in place with 7 bbl of 15.8 ppg cement using 2%e-coil Page 2 of 6 November 16, 2011, FINAL KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling 3. 2K-08BL1 Lateral(A4 sand,west) a. Swap from 2%"to 2"e-coiled tubing. Reconfigure BOPE for slimhole drilling;retest BOPE as needed. b. Set a monobore whipstock in the 31/4"liner at 9650' MD c. Mill 2.74"window with high-side orientation at 9650' MD d. Drill 2.70"x 3"bi-center lateral to TD of 12,570' MD e. Lay in over-balanced fluid prior to running liner f. Run 2%" slotted liner with an aluminum billet from TD up to 10,100' MD 4. 2K-08BL1-01 Lateral(A4 sand,west) a. Kick off of the aluminum billet at 10,100' MD b. Drill 2.70"x 3"bi-center lateral to TD of 12,145' MD c. Lay in over-balanced fluid prior to running liner d. Run 2%"slotted liner from TD up to 9640' MD, up inside the 31/4"liner 5. OPTIONAL: Run 31/4"x 4'/2" liner-top packer at 9200' to ensure isolation of the C-sand 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Directional - 20 AAC 25.005(c)(2) & 20 AAC 25.005(d) • See attached directional plans: 1. 2K-08B,plan#6 2. 2K-08BL1,plan#7 3. 2K-08BL1-01,plan#6 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-08B CTD laterals: >15,000' to property line, 1700' to the 2K-13 CTD laterals Casing Program ram 20 AAC 25.005(c)(6) • 2K-08B: 31/4", 6.6#,L-80,TC-II solid liner from 9200' to 9780' MD o Annular capacity(gauge hole)of the—580' of 31/4" liner is 3.3 bbl. o Proposed 7 bbl cement volume provides>100%excess cement compared to gauge hole • 2K-08BL1: 2%",4.7#,L-80, ST-L slotted/solid liner from 10,100' MD to 12,570' MD • 2K-08BL1-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 9640' MD to 12,145' MD Existing Casing/Liner Information: Surface: 9%",J-55, 36 ppf Burst 3520 psi Collapse 2020 psi Production: 7",J-55,26 ppf Burst 4980 psi Collapse 4320 psi Liner: 4'h",L-80, 12.6 ppf Burst 8430 psi Collapse 7500 psi Page 3 of 6 November 16, 2011, FINAL Or\ KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling Reservoir Pressure - 20 AAC 25.005(c)(4)(A) • Well 2K-08A does not penetrate the Kuparuk sands so there is no formation pressure measurement available in the immediate vicinity of the planned 2K-08B. The best indication of expected formation pressure was provided by the initial pressure measurement in the 2K-13A sidetrack in June 2011, 1700' to the south. It measured A-sand reservoir pressure of 3799 psi at 9050' MD, 6090' TVD, corresponding / to 12.0 ppg EMW. This well has been on pre-production for the last several months, so we expect formation pressure in the vicinity of 2K-08B to now be 3500 psi or 11.0 ppg. We have little data on the / differential pressure between the A-sand and the C-sand formations, but we generally expect pressures to be similar. We expect to encounter similar pressure as laterals are drilled away from the mother well. • Maximum potential formation pressure in 2K-08B is based on the 2M-14 injection well to the northwest, which in 2007 had measured formation pressure of 4527 psi at 6200 TVD for a pressure gradient of 14.0 ppg. In 2K-08B this gradient equates to a maximum potential formation pressure of 4492 psi(6171' TVD)and a maximum potential surface pressure of 3875 psi assuming a gas gradient to surface. / Mud Program - 20 AAC 25.005(c)(8) ✓ • Will use formate-based fluids(10.5 ppg planned, 10.0— 11.0 ppg possible)for milling operations and drilling the 2K-08B interval with the bighole CoilTrak assembly. We will use bromide-based Flo-Pro mud(10.5 ppg planned, 10.0— 11.0 ppg possible)for drilling operations in the subsequent slimhole horizontal laterals. • In all laterals we will have to lay in weighted completion fluid to over-balance formation pressure prior to running 3V solid liner and 23/8" slotted liner. The weight of the completion fluid is typically planned to match or slightly exceed the pressure held at the window during MPD operations. This targeted pressure at the window is as much based on hole stability considerations as it is over-balancing formation pressure. In 2K-08B(bighole, intermediate hole section)we plan to use 12.5 ppg fluid but it could be increased to as much as 13.0 ppg. In the 2K-08BL1 and 2K-08BL1-01 slimhole laterals we plan to use 11.8 ppg fluid but it could be increased to 13.0 ppg if needed. Managed Pressure Drilling: Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by " using drilling fluid hydrostatic pressure in combination with annular friction and applied surface pressure. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, independent of the BOPE choke. A minimum, constant over-balancing pressure is targeted at the window based on shale stability concerns and is adjusted as necessary based on reservoir pressure encountered during the drilling operation. Pressure at the 2K-08B Window(9425' MD, 5944' SSTVD, 6091' TVD) Using MPD—23/8" Coiled Tubing Pumps On (2.3 bpm) Pumps Off A& C-sand Formation Pressure (11.0 ppg) 3484 psi 3484 psi Mud Hydrostatic(10.5 ppg planned) 3326 psi 3326 psi Annular friction (i.e. ECD, 0.06 psi/ft) 566 psi 0 psi Mud + ECD Combined 3892 psi 3326 psi (no choke pressure) (overbalanced (underbalanced —410 psi) —160 psi) P at Window(12.5 ppg) 3959 psi 3959 psi Choke Pressure Required to Maintain 70 psi 630 psi Targe` Page 4 of 6 RI I f\J/\ [A November 16, 2011, FINAL KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling Pressure at the 2K-08BL1 Window(9650' MD, 6025' SSTVD, 6172' TVD) Using MPD-2" Coiled Tubing Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.0 ppg) 3530 psi 3530 psi Mud Hydrostatic (10.5 ppg planned) 3370 psi 3370 psi Annular friction (i.e. ECD, 0.035 psi/ft) 338 psi 0 psi Mud + ECD Combined 3708 psi 3370 psi (no choke pressure) (overbalanced (underbalanced -180 psi) -160 psi) Target BHP at Window(11.8 ppg) 3787 psi 3787 psi Choke Pressure Required to Maintain Target BHP 70 psi 420 psi BOPE - 20 AAC 25.005(c)(3) • Two well bore volumes of emergency kill-weight fluid will be available to the rig during drilling operations. The emergency kill-weight fluid may or may not be stored onsite,but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • Two BOP diagrams are attached. - The 2 -0 si a rac wi a rilled, cased, and cemented using 2%"coiled tubing. BOPE configuration for the `bighole BHA' will be used during these operations. We will begin drilling operations on 2K-08B using this BOPE configuration. The variable bore rams(2%"to 3'h"range) will provide secondary well control while running 31/4" liner. o The `slimhole BHA' BOPE configuration will be used for all remaining operations,which consists of drilling and lining the 2K-08BL1 and 2K-08BL1-01 laterals. These operations will be conducted with 2"coiled tubing. We will switch to this BOP configuration prior to running a whipstock inside the 3'/4"cemented liner. The 2%"rams will provide secondary well control while running 2%" liner. • Pipe rams,blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. The maximum potential surface pressure in 2K-08A is 3875 psi assuming a gas gradient to surface. 1/ • The annular preventer will be tested to 250 psi and 2500 psi. Liner Running: v • Since there is no SSSV,the 2K-08A CTD laterals will have to be displaced to an overbalancing fluid prior to running liner. See the"Mud Program"section for details. . • While running 31/4"solid liner,a floor valve with appropriate threads will be on the rig floor. The variable bore rams(2%"to 3%"range)will provide secondary well control while running 31/4" • liner. - • While running 2%"slotted liner, a joint of 2%"non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time,and the rig crew ✓ conducts a deployment drill with this emergency joint on every slotted liner run. The 2%"rams will provide secondary well control while running 2%"liner. Pressure Deployment of BHA: Double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA,and a slickline lubricator are used to deploy and undeploy the BHA under pressure. The BHA is too long to simply isolate by closing the double swab valves on the Christmas tree, so the BHA has to be lubricated under pressure. The pressure control equipment listed ensures there are always two barriers to reservoir pressure,both internal and external to the BHA, during the deployment process. During BHA deployment,the following steps are observed. The reverse is used for BHA undeployment. Page 5 of 6 O R I G I N i L November 16, 2011, FINAL KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling • Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. • Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. • When the BHA is spaced out properly,the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. • The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, external pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. Drilling Hazards - 20 AAC 25.005(c)(4)(B) & 20 AAC 25.005(c)(4)(C) ✓ • One significant drilling hazard in 2K-08A is uncertainty of formation pressure in the A-sand. The expected formation pressure is 3500 psi(i.e. 10.9 ppg), although there are offset wells that range from 14.0 ppg to 8.0 ppg. The A-sand horizontal laterals are targeting a relatively isolated and undeveloped fault block, increasing the degree of uncertainty. Use of Managed Pressure Drilling(MPD)techniques v will mitigate the risk. We have also shut in those offset wells with the most extreme pressure differentials to allow formation pressure to better equalize. • Shale stability is the major concern of the 2K-08B sidetrack. We will cut—35' TVD of Kalubik shale after exiting the 4'/2" liner. We will mitigate the potential for hole collapse by cutting this shale at 70° inclination or less and by ma+intaining a minimum 12.5 ppg ECD. In addition,we'll minimize exposure time by drilling as short an interval as possible and quickly running 31/4" liner across this shale. • Well 2K-08A has no measured H2S since it is a suspended well that does not penetrate the Kuparuk sands. Well 2K-07 is located 25' to the right side and 2K-09 is 25' to the left side of the 2K-08A surface location. Well 2K-07 has 38 ppm H2S and 2K-09 has 40 ppm H2S as of October 2011. The maximum H2S level on the pad is 63 ppm from well 2K-21A(October 2011). All H2S monitoring equipment will ✓ be operational. Waste Disposal - 20 AAC 25.005(c)(14) • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Page 6 of 6 November 16,2011, FINAL OR ! 4,,.. I N 1 :... 1 CD ._ CD 0 I.1 No cnO co U73 Q) a> _ 4.., > a3c in i tom O � _ as j b v O t3 M N N O Iftt CI N 0 cti 14 U L �_ U x U a� . O _ a w U a) a _>, MJ " >1N � > Q a3 w c U 2 w � Ya _ U � di -,-,. . a v ,:f,, U 0. c .c a., . . r, r, D U 3 U0 nm M m a g wLI O^ 44. mn KJf—, 6 n m r �a m m a 6 e? ORIGINAL Nabors CDR-2AC, Well 2K-08A Kuparuk Managed Pressure Coiled Tubing Drilling BOP Configuration for `Bighole' Ops: 2% Coiled Tubin 3" BHA, & 31/4" Liner Lubricator Riser �r 7 JJ Annula1 Blind/Shear 2%" Pipe/Slip(CT) Pump into Lubricator ><1><-1<1/<' I->\1><� � , , I above BHA rams OP 1r Choke 1 1 I 3" Pipe/Slip (BHA) I' Choke Equalize Manifold Variable rams (2%"-3%") li' Kill ►;O\ 1><>< Blind/Shear I 2%" Pipe/Slip(CT) IN 'I 7 r Choke 2 I Swab Valves V 44 ANL Wing Valves C1,44' Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi XI Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser ( r Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator >�J L \, above BHAAramsams ► l Choke 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/ I Slip(BHA) Kill ► <f� L><> > �> r _. Blind/Shear 2" Pipe/Slip(CT) Choke 2 Swab Valves Wing Valves hAtot Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi > Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union ORIGINAL 0 Z N t ti a to 4) � 7 Co nj O O O_ fZ O CO to O c-fi EN N .� C L N ^ N9 - -'a 7 -O 6J ^_ J m J O I- N O Y O 03 2 m o To o E to O CD O O N a ,k°,' Y [6 m (6 N y O) C.L. O O c,9 N N L RS _ p �' Co co 0 O N d C co tT m .- 61 - co N O •J N (6 _co M J N in M 3 N J y ^ W N W # - 00 O ^ Z O (6 (6 @ L • (fl m N@ d d — Lll O ILII Y 03 M X U a a) N o to a 0 L -I N L.L c O m Q- N a i` (13 - 0 - o -o m -- mac, ors! X 4 0 X v 2m L W • m 'Cl-) mccI e °' . a o 3 n 0- a o0 $ o o c 0 c •3 • o - E - o 0 O N Lc) Y c� LCO CO O ch 3 i6 ‘\ \y Cf) L 4F+ a) m H , ,�1 o d y t 11111111"1. M o J • N rn a� O p CLCr) O cid<O c fl I d7 N CO H C Q O - N O _ Cf COI _ to ^ f6 L O J 0 to 4i_� o LO 0 Lo c co2 N co `Y'- coo v N a �-N r- -§" Nf� .- L \ N COs a) co ' 3 v � m ORIGINAL ...ConocoPhil ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-08 2 K-08B Plan: 2K-08B_wp06 Standard Planning Report 02 November, 2011 'flu BAKER HUGHES ORIGINAL `.- ConocoPhillips or its affiliates Hp-- ConocoPhillips /rConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: 2K-08B Design: 2K-08B_wp06 Project Kuparuk River Unit ' Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2K Pad I Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N !From: Map Easting: 498,310.178 Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° I Well 2K-08 Well Position +N/-S 0.00 ft Northing: 5,938,425.30 ft Latitude: 70° 14'34.799 N +E/-W 0.00 ft Easting: 498,310.18 ft Longitude: 150°0'49.132 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.508 Wellbore 2K-08B Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 12/10/2011 16.33 79.81 57,353 Design 2K-08B_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,403.48 Vertical Section: Depth From(ND) +N/-S +EJ-W Direction (ft) (ft) (ft) (°) -118.50 0.00 0.00 265.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) ell OM) (°/100ft) (°/100ft) C) Target 9,403.48 63.56 266.08 5,934.60 813.07 -6,516.77 0.00 0.00 0.00 0.00 9,425.00 63.56 266.08 5,944.18 811.75 -6,536.00 0.00 0.00 0.00 0.00 9,450.00 66.17 267.72 5,954.79 810.53 -6,558.60 12.00 10.43 6.56 30.00 9,575.00 71.62 271.01 5,999.80 809.30 -6,675.14 5.00 4.36 2.63 30.00 9,780.00 62.83 276.75 6,079.14 821.76 -6,863.46 5.00 -4.28 2.80 150.00 11/2/2011 1:52:06PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL IPP:- ConocoPhillips or its affiliates ( ' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: 2K-08B Design: 2K-08B_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (ft) (°) e) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) I 9,403.48 63.56 266.08 5,934.60 813.07 -6,516.77 6,421.11 0.00 0.00 5,939,239.75 491,794.24 TIP 9,425.00 63.56 266.08 5,944.18 811.75 -6,536.00 6,440.38 0.00 0.00 5,939,238.43 491,775.02 KOP 9,450.00 66.17 267.72 5,954.79 810.53 -6,558.60 6,463.00 12.00 30.00 5,939,237.22 491,752.42 3 1 9,500.00 68.34 269.07 5,974.13 809.24 -6,604.69 6,509.02 5.00 30.00 5,939,235.94 491,706.34 ' 9,575.00 71.62 271.01 5,999.80 809.30 -6,675.14 6,579.20 5.00 29.48 5,939,236.01 491,635.89 4 9,600.00 70.53 271.67 6,007.91 809.85 -6,698.78 6,602.71 5.00 150.00 5,939,236.57 491,612.25 9,700.00 66.24 274.42 6,044.74 814.76 -6,791.59 6,694.73 5.00 149.79 5,939,241.50 491,519.46 9,780.00 62.83 276.75 6,079.14 821.76 -6,863.46 6,765.72 5.00 148.77 5,939,248.52 491,447.60 TD Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude I 2K-08B_T1 0.00 0.00 5,935.00 813.35 -6,516.96 5,939,240.03 491,794.05 70° 14'42.771 N 150°3'58.615 W I -plan hits target center -Point 2K-08B Polygon 0.00 0.00 0.00 1,043.37 -6,528.01 5,939,470.03 491,783.05 70°14'45.033 N 150°3'58.942 W -plan misses target center by 5939.07ft at 9403.48ft MD(5934.60 TVD,813.07 N,-6516.77 E) -Polygon Point 1 0.00 1,043.28 -6,527.66 5,939,469.94 491,783.40 1 Point 2 0.00 591.58 -6,527.54 5,939,018.28 491,783.42 1 Point 3 0.00 646.55 -6,946.20 5,939,073.34 491,364.82 Point4 0.00 1,054.18 -6,935.30 5,939,480.93 491,375.81 Point 5 0.00 1,043.28 -6,527.66 5,939,469.94 491,783.40 '2K-08B T2 0.00 0.00 6,080.00 793.29 -6,809.00 5,939,220.04 491,502.04 70°14'42.571 N 150°4'7.106 W -plan misses target center by 44.80ft at 9700.00ft MD(6044.74 TVD,814.76 N,-6791.59 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,763.50 2,751.86 9 5/8" 9-5/8 12-1/4 7,512.17 5,121.79 7"TOW 7 8-1/2 9,444.00 5,952.34 4-1/2" 4-1/2 4-1/2 19,780.00 6,079.14 3-3/16" 3-3/16 4 I - 11/2/2011 1:52:06PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates Fre ConocoPhilhps Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: 2K-08B Design: 2K-08B_wp06 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,403.48 5,934.60 813.07 -6,516.77 TIP 9,425.00 5,944.18 811.75 -6,536.00 KOP i 9,450.00 5,954.79 810.53 -6,558.60 3 9,575.00 5,999.80 809.30 -6,675.14 4 9,780.00 6,079.14 821.76 -6,863.46 TD 11/2/2011 1:52:06PM 1G1 a i, COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-08 2K-08B 2K-08B_wp06 Travelling Cylinder Report 02 November, 2011 vi BAKER HUGHES ORIGINAL ConocoPhillips or its affiliates r�' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Reference Site: Kuparuk 2K Pad MD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Site Error: 0.00ft North Reference: True Reference Well: 2K-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-08B Database: EDM Alaska Prod v16 Reference Design: 2K-08B_wp06 Offset TVD Reference: Offset Datum Reference 2K-08B_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer€ Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,403.48 to 9,780.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,175.20ft Error Surface: Elliptical Conic Survey Tool Program Date 11/2/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 32.50 7,432.50 2K-08 GyroData(2K-08) GYD-CT-CMS Gyrodata cont.casing m/s 7,434.17 7,669.77 2K-08A MWD(R500)(2K-08APB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,720.17 9,403.48 2K-08A(R1000)(2K-08A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,403.48 9,780.00 2K-08B_wp06(2K-08B) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (•.) (") 9,780.00 6,225.64 3-3/16" 3-3/16 4 3,763.50 2,898.36 9 5/8" 9-5/8 12-1/4 9,444.00 6,098.84 4-1/2" 4-1/2 4-1/2 7,512.17 5,268.29 7"TOW 7 8-1/2 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-08-2K-08A-2K-08A 9,425.17 9,425.00 0.00 0.82 -0.77 FAIL-Major Risk 2K-08-2K-08APB2-2K-08APB2 9,406.69 9,434.00 223.94 105.30 118.93 Pass-Major Risk 2K-08-2K-08BL1 -2K-08BL107 9,674.96 9,675.00 1.05 0.96 0.31 Pass-Major Risk 2K-08-2K-08BL1-01 -2K-08BL1-01_wp06 9,674.96 9,675.00 1.05 0.96 0.31 Pass-Major Risk 2K-13-2K-13-2K-13 Out of range 2K-13-2K-13A-2K-13A Out of range 2K-13-2K-13AL1 -2K-13AL1 Out of range 2K-13-2K-13AL2-2K-13AL2 Out of range 1 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/2/2011 8:55:39AM Page 2 of 7 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Reference Site: Kuparuk 2K Pad MD Reference: 2K-08A(D141)@ 146.50ft(D141 (28+118.5)) Site Error: 0.00ft North Reference: True Reference Well: 2K-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-08B Database: EDM Alaska Prod v16 Reference Design: 2K-08B_wp06 Offset TVD Reference: Offset Datum Reference Depths are relative to 2K-08A(D141)@ 146.50ft(D141 (284Coordinates are relative to:2K-08 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.02° Ladder Plot I I I 1 I I 220 I 1 1 I I I 1 1 1 I I I 1 I I I I I 1 1 I I I I 1 1 I I I I 1 I 1 1 I I I 1 I 1 I I 165 I I C I I I I I I I I 1 I I I 1 1 I I I I 2 I I I I I I J J _ ___J J J J _ _ a) I I I I 1 I I I I I 1 I L I 1 I I 1 I I I I I 1 I y-110 ' I 1 I I 1 I I I I I I I O I 1 I I I 1 I I 1 I I I I 1 1 I I I 'v I I 1 I I I I 1 I I 1 I 55 I I I I I I I I I I I I I I I I I 1 I I 1 1 _ _ I I I I I I I 1 I I 1 1 I I I 1 I I I I I I I 1 0 I I I 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND 2 K-08,2K-08A,2K-08A••.:Ll -- 2K-08,2K-080L1,2K-08BL1_07°5 •-..-2K-08.2K-08APB2,2K-OSAPB2VO 2K-0S,2K-08BL1-01.2K-08BL1�1_wpOd14 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/2/2011 8:55:39AM Page 7 of 7 COMPASS 2003.16 Build 69 0 RIGIN AL o .gm ,, , , ,,.,* _. • O 11111114) / a N a I 21 fi Ir -soN V. 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TRANSMITTAL LETTER CHECKLIST WELL NAME / � 2 — s PTD# 2 / Development Service Exploratory Stratigraphic Test Non-Conventional Well r / � p� FIELD: gEte-/t{, h' �l L POOL: / I `C— ��ll ` Z Ciel Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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