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198-159
• 07-0 116 / 5- 7 Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, May 03, 2018 4:09 PM To: Haggerty-Sherrod,Ann (Northland Staffing Services) Cc: Coberly,Jonathan; Loepp,Victoria T(DOA) Subject: RE: 1D-114 P&A Follow Up Flag: Follow up Flag Status: Flagged I would hold off on the report until all work has been completed. The sundry specified that the wellhead would be c ttit off and if that is going to happen in the next month or two we can wait for the report until then. Guy Schwartz Sr. Petroleum Engineer AOGCC SC iNEO JUN 1 S� 1 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Sent:Thursday, May 03,2018 3:36 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Subject: 1D-114 P&A Hi again Guy, 1D-114 is just a bit confusing for me. Here is the deal–this is a "Plug and Abandon—approved sundry#318-080" andli the rig has gone on to the well done all of the appropriate stuff and rigged down and moved off. However,the well head has not been removed, nor have we put on that final plate and covered the well. There is a very small chance that the remaining work might be finished in May but it is much more likely not to happen until August. Am I to wait until the final plate has been put on the well before I send a completion report? I really appreciate your help with all the questions I've had. Things seem to be a bit muddled this season. Thanks, Ann 1 i i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Q2/q 4#5118 DATE: 4/20/18 P. I. Supervisor t FROM: Austin McLeod SUBJECT: Plug Verification Lou Laubenstein KRU 1D-114 Petroleum Inspector ConocoPhillips Alaska PTD 1981590; Sundry 318-080 4/18/18: We traveled to location and met up with Randy Dolcater (CPAI) to witness a slickline plug tag inside 3 '/2" tubing (cement pumped in 2009; estimated top of cement at 5230 ft). The tool string consisted of weight bar, spang jars and a sample bailer with an assembly weight of 170 pounds. Three consecutive tags were made picking up 75 ft between tags, verifying top of cement at wireline measurement 4886 ft. Attachments: none 2018-0418_Plug_Verification_KRU_1 D-114_am.docx Page 1 of 1 Pio / 9% -/5 • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 17, 2018 2:55 PM To: Coberly,Jonathan Subject: Re: 1D-114 P&A (318-080, PTD: 198-159) Please tag with state witness. Thank you Victoria Sent from my iPhone On Apr 17, 2018,at 2:34 PM,Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>wrote: Victoria, I want to clarify if you would like one of your representatives to witness us to tag the deep cement plug on 1D-114? It wasn't in the sundry to do so, but I know we have had these witnessed before. We are currently RIH to retrieve the damaged production casing and tubing and regain drift access. We could be ready tomorrow to RU E-line and make the cement tag and deep tubing cut. Thank you for your clarification. Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska, Inc. 700 G Street,ATO 1378 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 SCANNED 1 • • ,a. o 0 co a-o a a a a a. a a asaaaaci, a (iaaaci M a E I- J O ' E Z >. U. U) o o Z a) a) d zCD c > O` Cl.) U)a ) m c c () m •o o a) E Q. LU U = co `Om • a) p , o0 . ToJ a CO c v o W a = N °00 �= c c a c o >. ,_ F- cQ a) a � � > EQ = � �� ,) uaa a CY oQ > co CD Q Z' c LIE J Nw .a) 0 CC OO Ni'i N 4 YN NO a e O NO ,_ a) m > E > E) coO aNn OONO Q a O a) o _ OO � � O _ acnaQo 00Ltc � Z0 _ co a) O al >, > Ctu - m ae i tat Z V• . Cl) — ca Qc Oz° v °'Iii _' �OD aaaaZaaaZa aaaaaaan. aa ,� ZOI- rtY Y o' O U) U) Qa 2 c c o o ) Y1 cvC� Z p c v 0 o � O c (}/) aci in' 3a) � ° tco m o O V °) a) c E o 0 o C9 m aa) ti o CO °I > o n 2 o N UU) 0) 0 - > > o ce aa) o o 0 0) QZ rna) c� JsA. co Ca?) cn a) c o a_ •`� > -' c � a c0 ° 0 Tr 9Li j I O - om . a o 0 o v p 9 c N 0 O O S` O 4? (n Y a) c ~ - V - _U a) V co Z H a) N }' 5 CC C� m ,- D N a) Z H o o N s N Q c E Q i 3 v rn Q cn . o con n >, O rn . v) J 'o . ' o a) N ._ o = a) a) cuco .Ca) •c a) O •c a3 >, p o 0 a5 �ati20Ctc000c1- Y L0 Oi 2 J co Q o W N E op, N v• Q CL a CL CL aaaaaaaaaaaa aaaa. _ U) N T-- a) 0 ,,, •� r Y m o 0 C4 .- O p c) co j Z o wO c c _ L I._ U Q F- V O o,Q Dc ii) 2a_ U) c J D W QDU YO fi a 'Sm co o -J -v a p 0C a a) 0 a) H co m N N N c �- Cn .c c oZ ,. via c Li N co (a. V ° c) a) > > `o cn c) O—p w r a w Z Z O 2 ,_ o a d a E E 0 c v > > 2 co aJ c c Ce 2 Q cm o) ,.. N rn J a) a) t0 o ca .a c c co tt CLc Y a) c a) > S -76 m z o 0 0)) 0 Q o rn 0 a) a) act o o c Q c 0 m o f E)Q coccco :Loo a -el-) 0 0 0 062o 3: c) � 3Qam3inoYF- i257o � co o 2 Alaska Oil and Gas of 7, THE STATE � 4 w�\ �%%/'�s� Conservation Commission-" ` i i 333 West Seventh Avenue "rW _ Anchorage, Alaska 99501-3572 ` GOVERNOR BILL WALKER Main: 907.279.1433 ra: Fax: 907.276.7542 oFALAS www.aogcc.alaska.gov Jonathan Coberly Workover Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1D-114 Permit to Drill Number: 198-159 Sundry Number: 318-080 Dear Mr. Coberly: 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, Hollis S. French Chair DATED this IS day of March, 2018. SCANNED J y RBD1V1S ,"n18 1 Y, FEB 2 8 2018 STATE OF ALASKA p7 . 3//51/ g1 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 0 Re air Well 0 Operations shutdown0 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture StimulateP Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program0 Alter Casing 0 Other 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 5.Permit to Drill Number: 2.Operator Name: 4.Current Well Class: • Exploratory ❑ Development ❑ 198-159 ConocoPhillips Alaska, Inc. 6.API Number: 3.Address: Stratigraphic 0 Service 0 , 500292290800' P.O. Box 100360,Anchorage,Alaska 99510 8.Well Name and Number: 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? N/A \ KRU 1D-114 Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 Kuparuk River Field/West Sak Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6144 4139 1238PS1 6144 NONE 6,270' 4,255' MD TVD Collapse Casing Length Size Burst Conductor 80' 16" 121' 121' Surface Production 6,218' 5 1/2 6,259' 4,245' ( ( Perforation Depth MD(ft): (Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): L-80 5,475' 5580-5562 3625-3881 3.500" Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for 3/15/2018 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 16.Verbal Approval: Op Shutdown 0 Abandoned 0 Commission Representative: GINJ 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Jonathan Coberly Jonathan Coberly Contact Name: Authorized Name: Contact Email: Jonathan.Coberly@cop.com Authorized Title: Workover Engineer Contact Phone: (907)265-1013 Authorized Signature: Date. 2'Z75" I I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry Number: 3 - 0`30 Plug Integrity BOP Test 132r.' Mechanical Integrity Test 0 Location Clearance 0 Other: 0 O -re 51 td a56 °p -J,I71 tit LCA ��r v �_ env/�,� � rz•�� � vtr �f ccs- c-�n�a'� t o 25 % 5 ,. /1 7 t'C S 5 C C( p h r7 G6 , g o AA� � ��f/ OC2 CC - VC-ria1i, c'z fa go fl.4C 25. 2e5 / Sor"k SCo r: c>,/low vi red r rl`g w P Post Initial Injection MIT Req'd? Yes 0 No (� /� no BOn� ��� O Lit/�, CCI /'✓I ,S't�P 5 � 'f"Gi�-v �/ Spacing Exception Required? Yes ❑ No Subsequent form Required: YS /o — � � p,-a��d�ca �� Ofi�� ha� /� CanCILC?C4 p 2 APPROVED BY 1 p Approved by: 1C(:)..,(:r1-----s _ COMMISSIONER THE COMMISSION Date: 3 f r S e, 1' 244/ , ,/c/i VTL 3//vd R I G I NAL ,c- Submit Form-and- ,, orrrren.,„ is C� A roved application is valid for 12 months from the date of approval. Attachments in Duplicate M,� Form 10-403 Revised 4/2017 Pp ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 28,2018 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for Change of Approved Program on an Application for Sundry Approval to plug and abandon the Kuparuk Injector 1D-114(PTD: 198-159). ID-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.MD with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft.MD. In January 2009,a cement plug was pumped to approximately 5,230 ft.MD.as a temporary barrier in preparation for a rig workover to repair the well.The well remains suspended for P&A. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A.Because of the tubing restriction at 145 ft.MD a deeper circulation point for cementing operations could not be established. During the off-rig P&A attempt in October 2015 CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft. MD. P&A operations were suspended. CPAI has exhausted all non-rig P&A options and gained sundry approval in October 2017 for an on-rig P&A of ID-114.The scope of the P&A was to stretch the tubing in attempt to re-gain drift access to create a circulation point for cement placement.If stretching didn't not re-gain drift,a surface cement plug to 145' MD would be placed in the well and followed by excavation and wellhead removal. Since October,CPAI has developed an alternative Plug and Abandonment scope to achieve a lower cement circulation point. The new scope involves installing a 10-3/4"casing guide string past the damaged 5-1/2" production casing and then removing the damaged production casing and tubing from the outside. It is believed that this method of repairing the damage from the outside has a higher chance of gaining a lower cement circulation point. If we are unable to gain the deeper cement circulation point with this method we request to f11 back to the October 2017 approved sundry to install the surface plug to plug and abandon this well. If you have any questions or require any further information,please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, Jonathan Coberly Workover Engineering Team Lead CPAI Drilling and Wells 1D-114 Plug and Abandonment (PTD #: 198-159) Current Status: The well is currently shut in isolated with a positive and negatively tested cement plug with the TOC estimated at 5,230' MD. There is a known production casing leak at approximately 150' MD. We are unable to drift a tubing cutting or punch device past the depth of a tubing restriction at 145' MD with anything larger than 1' length x 0.75"OD drift.There is currently a passing MIT-T on the tubing and cement plug to 1,500 psig. Scope of Work: Pre-rig cut tubing above the damage located at—150' MD. Remove the wellhead down to the conductor.Washover mill a 10-3/4"casing guide string past the damaged 5-1/2"production casing. Cement the guide string in place. Remove the damaged 5-1/2"production casing and the damaged 3-1/2"tubing strings past the damage. Gain deeper drift access to create TxIA communication above the existing cement plug. Pump cement to surface. General Well info: MPSP: 1,238 psi(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A,B,D-Sands—1,600 psi/3,625' TVD (8.5 ppg EMW)estimated from offset wells. Wellhead type/pressure rating: Vetco Gray,7 '/16" 5M Top x 16"Bottom Doyon 14 BOP Config: Annular/Variable Pipe Ram/Blind Rams/Mud Cross/Variable Pipe Ram MIT results: MIT-T/DDT—Passed to 1,500 psig/Opsig 2/5/2018 SCLD—Fluid shot at 150'MD 6/11/2008 Well Type: Injector Estimated Start Date: March 15,2018 Production Engineers: Marina Krysinski/Mitch Autrey Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) ' S11vh Remaining Pre-Rig Work , 'A.A., Excavate cellar and install cementing ports onto 16"conductor. e (5-0 2. Pre-rig cut tubing mid-joint above the subsided interval 133' MD. 1' Rig Work MIRU 1. MIRU on 1D-114. 2. Record shut-in pressures on the T&IA. If there is pressure,bleed off IA and/or tubing pressure and complete-3e=-- 24 ho yr- /V F1 . Retrieve Partial Tubing, & Remove Wellhead 3. ND tubing head adapter and tree. 4. MU landing joint and BOLDS. 5. Pull tubing to pre-rig tubing cut(^'133' MD). Re-cut on rig if pre-rig cut was unsuccessful. D 6. Set RBP in casing above tubing stub. Dump sand on top of plug. 7. Secure wellhead to rig and cut the production casing below the wellhead with drill pipe conveyed mechanical cutter. Cut conductor casing with Wachs cutter from the outside. Lift and remove the wellhead. 8. Install conductor load ring,drilling adapter,and drilling riser. •Page 1 of 2 Install New 10-3/4" Casing Guide String 9. MU 10-3/4"casing with overshot mill shoe and wash over 5-1/2" production casing from surface to"'600' MD. 10. Cement w/11 ppg LiteCrete(w/Fluid Loss and CemNet)down production casing by 10-3/4"casing annulus back through the 10-3/4"by conductor annulus ports leaving—100'of cement inside the 10-3/4"and cement to surface on the backside. Wash Over and Remove 5-1/2" Subsided Casing 11. ND Drilling Riser& Drilling Adapter. NU new tubing/casing head. PT wellhead connection. 12. NU BOPE and function test to 250/2,500 psig. �--- 13. Wash over production casing from surface in multiple runs with overshot mill shoes of reducing ID's to remove cement from OD of production casing past damaged zone at^'150' MD. 14. Cleanout sand a debris from inside of production casing to RBP and remove plug. 15. MU overshot cutter on wash pipe and cut production casing below damaged zone at' 150' MD. 16. MU spear and fish production casing to cut. Obtain Deeper Circulation Point & Pump Abandonment Plug 17. MU overshot cutter on wash pipe and cut tubing below damaged zone at' 150' MD. 18. MU overshot grapple and fish cut tubing section. Dress off tubing stub if needed. 19. MU overshot and engage tubing stub. RU E-line:drift and cut tubing mid tubing joint above the located TOC inside the tubing(calculated at 5,230' MD). RDMO E-line. 20. POOH with overshot tubing guide string. MU overshot grapple and engage tubing stub. PU and circulate balanced heavyweight fluid pill around cut depth. 21. POOH with tubing to laydown fishing BHA. 22. Circulate 15.8 ppg class G cement to surface. WOC. ND BOP,NU Tree 23. Confirm TOC is within 5'from surface. 24. ND BOPE. Install dryhole tree. RDMO. Wellhead Excavation/Final P&A 1. Cut off the wellhead and all casing strings at 4 feet below original ground level. 2. Perform Top Job and verify that cement is at surface in all strings. 3. Send the casing head w/stub to materials shop. 4. Weld on cover plate. 5. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. Page 2 of 2 Coberly,Jonathan From: Coberly,Jonathan Sent: Tuesday,February 27,2018 3:30 PM To: 'victoria.loepp@alaska.gov' Cc: Buck,Brian R Subject: 1D-114(PTD:198-159,Sundry:317.504) Attachments: 1D-114 90 day TIO trend 2-27-18jpg Victoria, In response to the questions earlier today over the phone on 10-114(PTD: 198-159,Sundry: 317.504) I have confirmed the data with the response below. I will submit a change of approved program sundry with this data included. Please let me know if you have questions or concerns. Confirm cement on the backside of the production casing? 1. Primary production casing cement job: a. Pumped 515 bbls 10.5 ppg lead cement&92 bbls 15.8-16.0 ppg tail cement. Saw 10.3 ppg cement returns at surface while pumping lead cement, but ultimately lost returns during tail cement and displacement pumping. Cement Plug barrier justification? 1. Cement plug pumped by displacement method down the tubing: a. 1/14/2009:"ONLINE WITH CEMENT PUMP. 1OBBLS WATER-3BPM,750PSl. 15BBLS 15PPG THIXOTROPIC CEMENT 4.5BPM, 1000PSI. 5BBL WATER 2.5BPM, 650PSI.3OBBL 9.6PPG VISCOSIFIED BRINE 5BPM, 1090PSI, 13.4BBL DIESEL 4BPM,750PSI." b. 1/15/2009: Unable to pass Tubing Mechanical Integrity Test. Plan to pump more cement. c. 1/17/2009: "PUMPING DOWN THE TUBING. 1OBBLS FRESH WATER, 27.5BBLS THIXOTRPOIC CEMENT, 5BBLS FRESH WATER, 28BBLS VISCOSIFIED 9.6PPG BRINE, 13BBLS DIESEL." Estimated cement top as high as 5,230' MD by displacement from 1/14/2009 pump volumes. d. 1/18/2009:Tubing Mechanical Integrity Test to 2,500 psig& Drawdown Test Passed e. 2/5/2018: Tubing Mechanical Integrity Test to 1,500 psig& Drawdown Test Passed 2. Surface pressure history: a. 2/5/2018: Pressures recorded pre and post MIT-T: Initial T/IA(2 psig/10 psig); Final T/IA(0 psig/10 psig) b. I attached the recent surface pressure history that our Well Integrity folks submit to the AOGCC for the 90 day TIO reporting exercise. Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska,Inc. 700 G Street,ATO 1378 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 1 KUP INJ 1D-114 onocoPhillips $, Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) AL-ISI,I,II;(., 500292290800 WEST SAK INJ 68.25 2,595.93 6,270.0 ConoGo8h111lps Comment HTS(ppm) Date Annotation End DateKB-Grd(k) Rig Release Date ••• SSSV: NONE Last WO: I 48.41 8/28/1998 10-114,2/28/2018 6:23.33 AM Last Tag Verlcal ooh rea0c.(acWal1..... Annotation Depth(ftKB) End Date Last Mod By Last Tag: 5,820.0 9/4/2005 WV5.3 Conversion Last Rev Reason Annotation End Date Last Mod By Rev Reason:WELL REVIEW I 5/22/2012 I osborl ' Casing Strings HANGER;39.3 f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I..Grade Top Thread 1 ` CONDUCTOR 16 15.062 41.0 121.0 21 0 62.58 H-40 WELDED • OD(in) Casing Description ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �vlaraf r1 PRODUCTION 5.5x3.5 51/2 4.950 40.8 6,258.7 4,244.7 15.50 L-80 ABM-BTC � `�' Tubing Strings LL,,,Tubing Description (String 3Ma..1/2.IID(in) 9922 (Top(ftKB)392(Set Depth5,475(It.81.JSet Depth(N3.531D)(..2..I Wt(Ib/k930) IGratleL-80 (TopABM Conn -CUEection TUBING . . 1III 111-1 Completion Details Top(ND)Top(ftKB) (ftKB)p( D) Top(°)Incl Nominal Item Des Com ID(in) CONDUCTOR,41.0-121.0 a 39.2 39.2 0.00 HANGER VETCO GRAY HANGER 3.500 5,430.2 3,490.6 27.58 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812 5,475.0 3,530.5 26.58 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date I ID(in) 6,144.0 4,139.3 23.30 I PLUG CIBP-INFLATABLE BRIDGE PLUG 5/1/1999 0.000 ' Perforations&Slots GAS LIFT;5,372.1 Shot 11.1kDens Top(ND) Btm(TVD) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (88(8) Zone Date ) Type Com s, 5,580.0 5,612.0 3,625.1 3,654.1 WS D,1D-114 5/3/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, 180 deg phase-CLOSED bk 5,650.0 5,678.0 3,688.5 3,713.9 WS B,1D-114 5/3/1999 4.0 (PERF 2.5"HC 31J UJ HMX DP, wPr're,s.a3o.2 h, 180 deg phase-CLOSED 5,684.0 5,688.0 3,719.4 3,723.0 WS B,10-114 5/2/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, 180 deg phase-CLOSED c 5,701.0 5,707.0 3,734.8 3,740.2 WS A4,1D-114 5/2/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, S. 180 deg phase-CLOSED ♦, , 5,717.0 5,722.0 3,749.3 3,753.9 WS A4,1D-114 5/2/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP, _ 180 deg phase-CLOSED { :1 5,748.0 5,754.0 3,777.5 3,783.0 WS A3,1D-114 5/1/1999 4.0 (PERF 2.5"HC 31J UJ HMX DP, SEAL ASSY,5,475.0 {.-!•.::,',,,,. 180 deg phase-CLOSED 5,776.0 5,781.0 3,803.0 3,807.5 WS A3,1D-114 5/1/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP, 180 deg phase-CLOSED ":,S, 5,790.0 5,796.0 3,815.7 3,8212 WS A3,1D-114 5/1/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, =i: 180 deg phase-CLOSED 1!N 5,824.0 5,836.0 3,846.7 3,857.6 WS A2,10-114 5/1/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, 180 deg phase-CLOSED 5,850.0 5,862.0 3,870.3 3,881.3 WS A2,1D-114 5/1/1999 4.0 (PERF 2.5"HC 3IJ UJ HMX DP, ;w: 180 deg phase-CLOSED .k Cement Squeezes PLUG;5,287.0 ftKB qM ^.a ' Top(ND) Btm(ND) (PERF;5,580.03,812.0 a4&''.. (ftKB Top ) ) Btm(ftKB)) (ftKB) (ftKB) Des Start Date Com ` 5,287.0 5,862.0 3,366.7 3,881.3 PLUG 1/17/2009 PLUG SET&TESTED TO 2500 PSI Mandrel Inserts IPERF;5,600.0-5,678.0 ' ,' St Stati ,t4 N Top(ND) Valve Latch Port Size TRO Run fi�+i Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com IPERF;5,684.0-5,608.0 6 11 5,372.1 3,439.6 CAMCO 3.5 x 1 1 GAS LIFT DMY INT 0.000 0.0 8/27/1998 4 V.. Notes:General&Safety 4:9.; End Date Annotation IPERF;5,701.0-5,707.0 Ms.,, 1/18/2009 NOTE:VERIFY P 8 A,CEMENT PLUG TESTED @ 2500 PSI ON 1/18/2009 N8/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;5,717.03,722.0 ��FS IPERF;5,748.0-5,754.0 • IPERF;5,776.0-5,781.0 ' k 4i 4 1 IPERF;5,790.03,796.0 ;3 ill\ IPERF;5,824.0-5,838.0 i 'ps IPERF;5.850.0-5,862.0 f' Aub cement plug;5,287.0 ftKB w •.- PLUG;6,144.014 PRODUCTION 5.5015;40.8- 6,258.7 1D-114 ConocoPhillips West Sak Injector Proposed P&A EXISTING PROPOSED Vetco Gray Wellhead System Dry Hole Tree (Post RWO Surface WH Removal) r lir/ �� ; 1 / / 16" 62.5# H-40 WLD, 121' MD ► ' -4111---—150' MD 5'/2" Suspected Casing Leak r r - 10-3/4"45.5#L-80 HYD563, —600' MD �0� r, ijf ef' 21 / Ir ' I 5-'/2" x 3'/z" 26#J-55 BTC, 6,259' MD I ;, 1 r'` // f/ ,;+ 1 4 / r: 1 I / 1 1 F fl Tubing cut/perf mid-joint above TOC I 5,230' MD Estimated TOC Plug I. I f I` I I I 'I 2. } �,,, 7 r. 4 1 4( 00 If 1 G ij I FI ( '1 Date: 13-Feb-2018 I Drawn By: Jonathan Coberly , t a , ko a ,,,,... .... .$ n 8 - tu 1 a z a cc a. cc' ..,. , 0 1.1 •,.. U › , 32ap F..` g R .94 0 0 0 el 01 N VI ST-C4al"U' Ht (pi I e 8I-cPi-C)T 81 cial-91 8T-q -6 81-qa3-6 0 8I-ciai-Z n. ....d W 02 UI".• C I re 8T-qaj-z t--- ST-uef-Sz Ill §". c Si-uellt ( a. ° A .4 4 u C 0 SI-uef-6I 0 "4 'a as St-uef-6I I 2 .--m C 8 i-tle 1-Z1 I E 0 E 131-uef?I I 0 to ...., (..) 0. C. st-uer-s m gi-uer-S —3- c I c C.3 < LI-3.70-6Z 0 LI-a40-6? I 4 N- °..'. LI-3aG-ZZ /I ).1t1 e( Ii — — u. 0') IT-3att-si N 4..4 LI-NICI-SI ;6 — ZI-3,13-8 LT-3a0-ft a) . nJ 0 Oa 10 ea. N 0 el VI oq N 40 441 tr. trt N el 0 1.4 el 006000000 ' ; "el iSd ac110'Cli)StAl cn c-.3 UJ hw�,A___s�, THE STATE Alaska Oil and Gas lhos . xl, o.fA © s (A Conservation Commission 013011.-:::-.'7.41-- 333 West Seventh Avenue r :111 r GOVERNOR BILL WALKER Anchorage,Alaska 99501-3572 Q '' �, Main:907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sara Heskin Associate Well Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 1D-114 Permit to Drill Number: 198-159 Sundry Number: 317-504 Dear Ms. Heskin: 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, tOCC----t_______________l Hollis S. French Chair r DATED this day of November,2017. V"rte : .; STATE OF ALASKA OCT 25 An/ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon U Plug Perforations U Fracture Stimulate U Repair Well U Operations shutdown L Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing❑ Other 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillios Alaska. Inc. Exploratory ❑ Development 0 198-159 3.Address: 6.API Number. Stratigraphic ED Service 0 P.O.Box 100360,Anchorage,Alaska 99510 500292290800 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0KRIJ 1D-114 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,270' 4,255' 1255 5,287',6,144' none - Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface Intermediate Production 6,218' 8" 6,259' 4,245' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): From 5,580'to 5,562' From 3,625'to 3,881' 3.500" L-80 5,475' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No packer,no SSSV N/A 12.Attachments: Proposal Summary O Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic D Development❑ Service 0 14.Estimated Date for 1-Nov-17 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ n WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG f] GSTOR n SPLUG n Commission Representative: GINJ n Op Shutdown n Abandoned I -, 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sara Heskin Contact Name: Sara Heskin Authorized Title: late Wells Engineer Contact Email: Sara.Heskin@cop.com f n Contact Phone (907)265-1027 Authorized Signature: MX(.UA Date: I V " 24- 14- COMMISSION COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 17 5°t4 Plug Integrity rvir BOP Test Er Mechanical Integrity Test 0 • Location Clearance Other. 43ebc, 7/ 57` 7t_15 2 5-061 51.5' • 4nr7Lr)ar pi r'vrri-t1,-- f--PS f ±0 2-5704) (1.s�,feipj J O G G Yt?r"r""1-7r 6,Gc tAil t 55.5 C P h oft) CT Post Initial Injection MIT Req'd? Yes (]No / a ,_ rj p i'-rd Spacing Exception Required? Yes n No Subsequent Form Required: /0 —4G Approved by: ell APPROVED BY COMMISSIONER THE COMMISSION Date: t t (3 U! P LI CAT E Submit Form and form10.403Revised4/2017 Approvedapplication isvalidf 2 n f er I. Attachments in Duplicate ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 24'h,2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 71h Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ( ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon (P&A)West Sak injector 1D-114(PTD#: 198-159). 1D-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.MD with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in,casing at 150 ft.MD. In January 2009,a cement plug was pumped to approximately 5,230 ft.MD.as a temporary barrier in preparation for a rig workover to repair the well.The well did not meet economic metrics for a repair and remains suspended for P&A. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A.Because of the tubing restriction at 145 ft.MD a deeper circulation point for cementing operations could not be established. Per 20 AAC 25.112 well plugging requirements,"Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment." During the off-rig P&A attempt in October 2015 CPAI was unable to obtain confirmation that kill weight fluid remained in the IA. It is believed that the fluid exited the production casing through the leak at 150 ft.MD,thus P&A operations were suspended. CPA1 has exhausted all non-rig P&A options and therefore requests sundry approval for an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement.If stretching does not re-gain drift,the tubing will be pulled.- -is-e€Kill weight fluid will be placed in the well and allowed to swap into the 5-1/2 in.x 3-1/2 in.annulus and 3-1/2"tubing from the seal assembly to the base of permafrost.Next,a cen,eai retainer will be run at approximately 140'and cement will be squeezed )w the retainer into the suspected casing leak. Then a surface cement plug will be installed from approximately 115 ft. 140'MD to surface ifl-t#te. r .arrt#.tthi+rg, followed by excavation and wellhead removal. The well has 5-1/2 in,x 3-1/2 in.production casing to 6,270 ft.MD.There is 3-1/2 in.tubing to 5,475.8 ft. MD. Ten sets of perforations in the West Sak formation,with the top perforation at 5,580 ft.MD If you have any questions or require any further information,please contact me at 265-1027 or sara.heskin@conocophillips.com. Sincerely, --- Fes. So. es ; Sara Heskin Associate Wells Engineer (�rt� Suck CPAI Drilling and Wells ROO Cui+Ple,t•;a»s ' o7- 5- ,22.(, t1f3/zo1� KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 CURRENT STATUS: 1D-114 is currently shut in under Suspended status with the cement plug isolating the reservoir.This well was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft. KB with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft.KB. In January 2009,a cement plug was pumped to approximately 5,230 ft. KB.as a temporary barrier in preparation for a rig workover to repair the well; However,the well did not meet economic metrics to repair. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A.Due to the tubing restriction at 145 ft.KB a deeper circulation point for cementing operations could not be established. During the off-rig P&A CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft. MD,thus P&A operations were suspended due to the inability to confirm the fluid barrier.The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft. MD and 3-1/2 in.tubing to 5,475.8 ft. KB. Ten sets of perforations are in the West Sak formation,with the top perforation at 5,580 ft.MD. SCOPE OF WORK: CPAI has exhausted all non-rig P&A options and therefore is planning an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement. If stretching does not re-gain drift,the tubing will be pulled.CPAI intends to cement to surface from as deep as drift access will allow,but at minimum will cement from 34-5'-140'MD to surface with KWF placed between the existing reservoir cement plug and surface plug.41 barrels of Kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in.annulus,from the seal assembly to the base of permafrost. Next,a cement retainer will be run at approximately 140'and cement will be squeezed below the retainer into the suspected casing leak.The surface cement plug will be installed from approximately-45 ft 140' MD to surface in the IA and tubing,followed by excavation and wellhead removal. Well Type: West Sak Single-Casing Injector MPSP: 1255 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,255 psig=(1,600 psig-(0.1 psig/ft*3,441'TVD)) Formation Pressure: Max Pressure between Seal Assy.and Base Permafrost-1,600 psi/3,448'TVD Greatest Formation Pressure between Plugs at Time of Abandonment Hydrostatic Calculations: Base of permafrost=1,651.3 ft.TVD(=1,766.8 ft MD) Depth of seal assembly: 5,475.0 ft.MD=3,448.1 ft.TVD Maximum pressure between seal assembly and base of permafrost=1,600 psi/3,448'TVD Annulus contains diesel and brine. Assume diesel to base of permafrost: Hydrostaticd;esel =0.354 psi/ft* 1,651 ft.TVD=584 psi KWF=(1,600 psi-584 psi)/(3,448-1,651 ft.TVD)=0.565 psi/ft=10.9 ppg Wellhead Type: Vetco Gray(GE) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/2,500 psig(2,500 psig high for Annular) Integrity Results: Cement Plug Positive&Negative Pressure Tests to 2,500 psi 1/18/09 MIT-T to 2,500 psi 7/1/15 5-1/2"Casing Leak at"150' MD identified 6/12/08 Earliest Start Date: 1-November-2017 Production Engineers: Pete Fox Page 1 of 4 KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 Workover Engineer: Sara Heskin (907)265-1027 sara.heskin@conocophillips.com SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Proposed Pre-Rig Work: 1. Function-test all T, I.C.,&O.C. LDS. Test tubing,I.C.,&O.C.pack-offs(T-POT/T-PPPOT/IC-POT/IC-PPPOT/ OC-POT/OC-PPPOT).(Completed) 2. Measure T&IA fluid levels. Proposed Rig Workover Procedure: 1. Confirm that an approved sundry has been received from AOGCC. 2. MIRU RWO Rig on well 1D-114. 3. Observe the well for flow for 30 minutes to verify well is static. 4. Install BPV&blanking plug, ND tree,NU BOPE&test to 250/2,500 psi low/high. 5. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat tubing hanger. 6. P/U 20 Klbs to stretch the 3%"tubing. 7. R/U wireline in an attempt to drift tubing,tag top of the cement plug,and punch holes in tubing as deep as possible. If successful,attempt to circulate cement through tubing punch a. If top of cement plug is more than 200'from estimated depth contact RWO engineer. b. If the assembly does not drift the obstruction at '150'MD, increase surface overpull 10%tubing tensile-yie444-lirmits to 40 Klbs and attempt to drift tubing. Do not attempt to part tubing. i. If tubing parts shallower than^'140',attempt to regain access to tubing. ii. If tubing parts deeper than"'140',proceed to load the well with 45 bbls of KWF between the top of the seal assembly and the base of the permafrost,attempt a balanced cement plug from deepest point accessible if below suspected leak, then proceed to install a cement retainer, squeeze cement,and pump a surface cement plug. c. Drift tubing and tag TOC.(Estimated at 5,230'MD) d. Punch holes in first full joint above the top of cement,or as deep as possible to create TxIA communication. e. RD Wireline. f. Circulate through TxIA communication to ensure adequate rate for cementing. g. Follow cement with KWF(9.6 ppg). h. RIH with E-line and drift/tag TOC. RIH with E-line string shot and then chern cutter to cut first full joint above TOC.RD E-Line: 8. Assuming the deep drift was not successful, RIH and cut tubing as deep as possible,not in a coupling.Pull out tubing above cut. 9. If drifting past tight spot at-150'was not possible,load well with 150 bbls of 9.6 ppg KWF, and allow fluid to swap to the area between the top of the seal assembly and the base of the permafrost in accordance with 20 AAC 25.112.(F). 10. RIH with 5-1/2" 15.5#casing scraper to^'140'. 11. PU,MU and RIH w/cement retainer as deep as possible above where casing is scraped. 12. Set cement retainer.Confirm injectivity by pumping 10 bbls KWF below retainer. . Page 2 of 4 . 0 KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 13. Rig up cement unit. Squeeze cement into casing leak by pumping 15.7 ppg Arctic Seti cement. Overflush cement retainer by 1 bbl if squeeze pressure not obtained.Repeat cementing operation until squeeze pressure obtained. 14. If squeeze is successful,snap out of cement retainer.Pressure test cement retainer to 1500 psi. 15. Lay in cement on top of the cement retainer on way out of the hole to surface inside 5-1/2" casing, no more than 5'below original ground level. 16, RU cement equipment is rtstall-strr#aee-plug - ._ - . fi: Volume in 3 1/2 in.x 5.5 in.annulus-145 ft.x 0.0119024 bbl/ft-1.7 bbl ii-i: Excess: 30 bbl iv: Total volume-1.3+1.7+30-33 bbl for repeat cement job. RU IRS and PT equipment. 19. Performoven v4own test err-tubing a+ld-1A to_ -• .. • - . 20. N/D BOPE,N/U dry hole tree. 21. RDMO RWO Rig. Wellhead Excavation/Final P&A: 1. Remove the Well House(if still installed). 2. Bleed off T/I/0 to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found,have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings.AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop.Photo document. 8. Weld%"thick cover plate(16"O.D.)over all casing strings with the following information bead welded into the top. Photo document.AOGCC Witness Required. ConocoPhillips 1D-114 PTD#: 198-159 API #: 50-029-22908-00 Page3of4 KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska 9. Remove Cellar.Back fill cellar with gravel/fill as needed.Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. 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. • Page4of4 - d KUP 1D-114 ConocoPhillips 8 Well Attributes Max Angle&MD TD Wellbore API/UWIField Name Al r1ik,It1. (Wall Statue Incl(°) MD(51(8) Act Bhn(ftK6) CanooWYllips 500292290800 WEST SAK INJ 68.25 2,595.93 6,270.0 °_° Comment 1129(ppm) Date Annotation End Data KB-0,4(k) Rig Release Date Well CooOa:-1D-114,521/2012 11:1]48 AM SSSV:NONE Last WO: 48.41 8/28/1998 Schematic-Acluel Annotation Depth(ftKB) End Dale Annotation Lent Mod...End Date .... Last Tag: 5,820.0 9/4/2005 Rev Reason:WELL REVIEW osborl 5/22/2012 Casing Strings -.. /® Casing Description String 0.., String ID...Top((WS) Set Depth(f...Set Depth(TVD)...String Wt...String...St Ing Top Thrd HANGER,ss ,,'1.... CONDUCTOR 16 15.062 41.0 121.0 121.0 6258 H-40 WELDED �" Casing Description String 0... String ID...Top(1168) Set Depth(f...Set Depth(TVD(...String Wt...String...String Top Thrd al, PRODUCTION 51/2 4.950 40.8 6,258.7 4,244.7 15.50 L-80 ABM-EUE 5.5x3.5 Tubing Strings 6 " '4'7-'6" 5 425 , , N '-,v,Tubing Description String 0... String ID...Top(NKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 31/2 2.992 39.3 5,475,8 3,531.1 9.30 L-80 ABM-EUE Completion Details Top Depth t..- (TVD) Top Incl Noml... CONCUCTOR_ Top(1tKB) (R< ) (°) Item Description Comment ID(In) 41-tzt 39.3 39.3 -0.28 HANGER VETCO GRAY HANGER 3.500 5,430.2 3,490.7 27.58 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812 E 5,475.0 3,530.3 25.66 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 , Other In Hole(Wlrellne retrievable plugs,valves,pumps,fish,etc.) I 'a Top Depth IND) Top Incl Top(ItKB) (kKB) (°) Description Comment Run Data ID(in) ;4 6,144.0 4,139.3 23.29 PLUG CIBP-INFLATABLE BRIDGE PLUG 5/1/1999 0.000 GAS LIFT, 5,372 ' Perforations&Slots }} Shot it Top(ND) Bhn(TVD) Dens Top(1168)Btm(kKB) (kKB) (MB) Zone Date (ah^• Type Comment ### 6580.0 6612.0 3,625.2 3,654.2 WS D,10.114 5/3/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED 6650.0 5,678.0 3,688.6 3,713.9 WS B,10-114 5/3/1999 4.0(PERF 2.5"HC 3IJ UJ HMX DP,180 deg NIPPLE.s.430 phase-CLOSED 5,684.0 5,688.0 3,719.4 6723.0 WS B,1D-114 5/2/1999 4.0(PERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 6701M 6707,0 3,734.8 3,740.2 WS A4,1D-114 5/2/1999 4,0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg z phase-CLOSED ti 6717.0 6722.0 3,749.3 6753.9 WS A4,10-114 5/2/1999 4.0 IPERF '25"HC 3IJ UJ HMX DP,180 deg t phase-CLOSED SEAL ASSY. MI, 5,748.0 5,754.0 3,778.2 3,783.6 WS A3,1D-114 5/1/1999 4.0(PERF 2.5"NC 3IJ UJ HMX DP,180 deg 5.275 :r phase-CLOSED PLUG,5287 ��,.,.t.:i 5, 776.0 5,781.0 3,803.4 3,807.9 WS A3,10-114 5/1/1999 4.0(PERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,790.0 5,796.0 3,816.1 3,821,5 WS A3,10-114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,824.0 5,836.0 3,846.8 3,857.7 WS A2,1D-114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,850.0 5,862.0 3,870.4 3,881.3 WS A2,1D-114 5/1/1999 4.0(PERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED Notes:General&Safety End Date Annotation IPERF ,' 1/18/2009 NOTE:VERIFY P 8 A,CEMENT PLUG TESTED @ 2500 PSI ON 1/18/2009 5,580-5,612 ':•: 8/18/2010 NOTE:View Schematic w/Alaska Schemalic9.0 IPERF, 5,850-5,979 IPERF. 5.684-5,088 IF, • 5,701P.5ER,707 PERF, 5.717-5,722 IPERF. ( 5,748-s,7s4 IPERF, 57785,701 PERF, r 5.780-5,708 . li PERF. ;. Mandrel Details 5.824.5,836 y Top Depth Top Port - (TVD) Incl OD Valve Latch Sire TRO Run Ste Top MKS) (kKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Corn... IPERF, 1 5,372.1 3,439.7 29.60 CAMCO 3.501 1 GAS LIFT DMY INT 0.000 0.0 8/27/1998 5.85os,ee2 PLUG,6,144 PRODUCTION 55.35, 41-9,258 TD,0,270 1D-114 ConocoPhillips West Sak Injector Proposed P&A Vetco Gray Wellhead System Dry Hole Tree (Post RWO Surface WH Removal) 11] 1 1 [I I I - I I I I I Surface,to I Cement I 140'MD P&A 1 1.1-- 16"62.5#H-40 WLD, 121'MD ►lamt Cement 1---- –150'MD 5-1/2"Casing Leak I fEELiH "le— Retainer 5-1/2"x 3-1/2" 26#J-55 BTC, 6,259'MD ► Permafrost, 1,767'MD 9.6 ppg KWF I 5,230' MD Estimated TOC Plug 1 • t . e 5,372'MD Camco 3'/2" KBG-29 GLM ir 1 I I 5,430'MD Camco 3-1/2" DS Nipple -' L off'` 5,479'MD Baker GBH-22 Seal Assembly and L �` ,' 9 1 I Seal Bore Extension --'.► I V I w/5-;4"x3-;4"xo 3 I I I I = e, I n. I West Sak Perforations I I .` 5,580.0–5,612.0' MD 5,748.0–5,754.0 'MD a [J.- ` .r 5,650.0–5,678.0' MD 5,776.0–5,781.0 'MD `="' 5,684.0–5,688.0' MD 5,790.0–5,796.0'MD 5,701.0–5,707.0' MD 5,824.0–5,836.0 'MD I 5,717.0–5,722.0'MD 5,850.0–5,862.0 'MD I -'-. II I 1 / 6,144'MD Inflatable Bridge Plug I 1 1 I Date: 24-Oct.-2017 I Drawn By: Sara Heskin ConocoPhillips OCT 2 5 2011 Alaska P.O.BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 October 24th,2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon (P&A)West Sak injector 1D-114(PTD#: 198-159). 1D-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.MD with a 1.57 in. lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft.MD. In January 2009,a cement plug was pumped to approximately 5,230 ft.MD.as a temporary barrier in preparation for a rig workover to repair the well.The well did not meet economic metrics for a repair and remains suspended for P&A. 1 In October 2015 sundry approval 315-593 was grated to perform an off-rig P&A.Because of the tubing restriction at 145 ft.MD a deeper circulation point for cementing operations could not be established. Per 20 AAC 25.112 well plugging requirements,"Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment." During the off-rig P&A attempt in October 2015 CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft.MD,thus P&A operations were suspended. CPAI has exhausted all non-rig P&A options and therefore requests sundry approval for an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement.If stretching does not re-gain drift,the tubing will be pulled.44 barrels of kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in.annulus,from the seal assembly to the base of permafrost, prior to pumping a surface cement plug.The surface cement plug will be installed from approximately 145 ft.MD to surface in the IA and tubing,followed by excavation and wellhead removal. The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft.MD.There is 3-1/2 in.tubing to 5,475.8 ft. MD. Ten sets of perforations in the West Sak formation,with the top perforation at 5,580 ft.MD If you have any questions or require any further information,please contact me at 265-1027 or sara.heskin@conocophillips.com. Sincerely, SOIA Pfl'eAkAL Sara Heskin Associate Wells Engineer CPAI Drilling and Wells DUPLICATE KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 CURRENT STATUS: 1D-114 is currently shut in under Suspended status with the cement plug isolating the reservoir.This well was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.KB with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft.KB. In January 2009,a cement plug was pumped to approximately 5,230 ft.KB.as a temporary barrier in preparation for a rig workover to repair the well;However,the well did not meet economic metrics to repair. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A. Due to the tubing restriction at 145 ft.KB a deeper circulation point for cementing operations could not be established. During the off-rig P&A CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft. MD,thus P&A operations were suspended due to the inability to confirm the fluid barrier.The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft. MD and 3-1/2 in.tubing to 5,475.8 ft.I<B. Ten sets of perforations are in the West Sak formation,with the top perforation at 5,580 ft. MD. SCOPE OF WORK: CPAI has exhausted all non-rig P&A options and therefore is planning an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement.If stretching does not re-gain drift,the tubing will be pulled.CPAI intends to cement to surface from as deep as drift access will allow,but at minimum will cement from 145' MD to surface with KWF placed between the existing reservoir cement plug and surface plug.44 barrels of kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in.annulus,from the seal assembly to the base of permafrost.The surface cement plug will be installed from approximately 145 ft. MD to surface in the IA and tubing,followed by excavation and wellhead removal. Well Type: West Sak Single-Casing Injector MPSP: 1255 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,255 psig=(1,600 psig—(0.1 psig/ft*3,441'TVD)) Formation Pressure: Max Pressure between Seal Assy.and Base Permafrost—1,600 psi/3,448'TVD Greatest Formation Pressure between Plugs at Time of Abandonment Hydrostatic Calculations: Base of permafrost=1,651.3 ft.TVD(=1,766.8 ft MD) Depth of seal assembly: 5,475.0 ft. MD=3,448.1 ft.TVD Maximum pressure between seal assembly and base of permafrost=1,600 psi/3,448'TVD Annulus contains diesel and brine. Assume diesel to base of permafrost: Hydrostaticdieset=0.354 psi/ft* 1,651 ft.TVD=584 psi KWF=(1,600 psi—584 psi)/(3,448—1,651 ft.TVD)=0.565 psi/ft=10.9 ppg Wellhead Type: Vetco Gray(GE) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/2,500 psig(2,500 psig high for Annular) Integrity Results: Cement Plug Positive&Negative Pressure Tests to 2,500 psi 1/18/09 MIT-T to 2,500 psi 7/1/15 5-1/2"Casing Leak at—150'MD identified 6/12/08 Earliest Start Date: 1-November-2017 Production Engineers: Pete Fox Workover Engineer: Sara Heskin (907)265-1027 sara.heskin@conocophillips.com Page 1 of 5 KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Proposed Pre-Rig Work: I. Function-test all T, I.C.,&O.C. LDS. Test tubing, I.C.,&O.C.pack-offs(T-POT/T-PPPOT/IC-POT/IC-PPPOT/ OC-POT/OC-PPPOT).(Completed) 2. Measure T&IA fluid levels. Proposed Rig Workover Procedure: 1. Confirm that an approved sundry has been received from AOGCC. 2. MIRU RWO Rig on well 1D-114. 3. Observe the well for flow for 30 minutes to verify well is static. 4. Install BPV&blanking plug, ND tree,NU BOPE&test to 250/2,500 psi low/high. 5. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat tubing hanger. 6. P/U to stretch the 3%"tubing. 7. R/U wireline to drift tubing,tag top of the cement plug,and punch holes in tubing as deep as possible. a. If top of cement plug is more than 200'from estimated depth contact RWO engineer. b. If the assembly does not drift the obstruction at —150'MD, increase surface overpull in 10% tubing tensile yield limits and attempt to drift tubing. i. If tubing parts,attempt to regain access to tubing. c. Drift tubing and tag TOC.(Estimated at 5,230'MD) d. Punch holes in first full joint above the top of cement,or as deep as possible to create TxIA communication. e. RD Wireline. 8. Circulate through TxIA communication to ensure adequate rate for cementing(+/-2 bpm<=2,000 psi) 9. Load 45 bbls of 10.9 ppg. KWF between the top of the seal assembly and the base of the permafrost in accordance with 20 AAC 25.112.(F). 10. RU cement equipment to install surface plug. a. Rig up to pump down the tubing and take returns up the production casing annulus. b. Cement Volume Calculations: i. Volume in tubing=145 ft.x 0.00869627 bbl/ft=1.3 bbl ii. Volume in 3-1/2 in.x 5.5 in.annulus=145 ft.x 0.0119024 bbl/ft=1.7 bbl iii. Excess: 30 bbl iv. Total volume=1.3+1.7+30=33 bbl v. CPAI plans to install cement from the deepest circulation point to surface.At minimum,the plug will be installed 145'MD to surface as outlined in the subsequent steps. c. Pump 3 bbls fresh water spacer and".33 bbls of 15.7 ppg AS Cement. d. If no pressure increase is seen,close IA and squeeze 5-10 bbls of cement.Monitor for pressure increase. Open IA and circulate cement to surface. i. If returns are not to surface after all cement is pumped,displace the tubing volume allowing T x IA circulation point to remain open for repeat job. • Contact RWO engineer to discuss plan forward and notify AOGCC of path forward for repeat cement job. e. RD cement equipment and WOC as per planned slurry&surface sample. Page 2 of 5 ( KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 11. RU LRS and PT equipment. 12. Pressure test tubing and IA to 1,500 psi.to confirm barriers in place.Record results. 13. Perform drawdown test on tubing and IA to confirm barriers in place.Record results. 14. N/D BOPE,N/U dry hole tree. 15. RDMO RWO Rig. Wellhead Excavation/Final P&A: 1. Remove the Well House(if still installed). 2. Bleed off T/I/0 to ensure all pressure is bled off the system. 3. Remove the production tree,in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found,have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings.AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld%"thick cover plate(16"O.D.)over all casing strings with the following information bead welded into the top. Photo document.AOGCC Witness Required. ConocoPhillips 1D-114 PTD#: 198-159 API #: 50-029-22908-00 ) 9. Remove Cellar.Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. 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. Page 3 of 5 g KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 m Alaska 1 KUP 1D-114 a T ConocoPhillips lig Weil Attributes P MaxMaXAngie)(( TD A1.,Aa.A c Wpl500202OIRVI2000 Fw10 WEST 50 Welt Shtue Incl(') 1MO Irate) not elm 761261 500292290300 SPJ< ...__ Conmp,YviprINJ 68,25 2,595.93 6,270.0 ..• Comment 025(ppm) Dab IAnnotaoan End Date 1KBGni(h) RI9 RMease Dara 1. WMc,'-10-11%27/70121 IT4e.w SSSV:NONE L.o(WO: 4841 820(1998 Annotation Donn,(RIM End 0.5 Annobti on -Leal Nad._End Orta 1 Last Tag' 0820.0 9/4/2005 I Rao Reason:WELL REVIEW DSDOA 15/77/2012 k Casing Strings IIILaing Deaedplion SWny O,. String lD_.Too(ryKa1 SM D.pdr IL..Set DeplE RVDI-.;Striny Vit_.Shiny...Stdnp Top Tlvd R.wcm.0e CONDUCTOR 16 15.062 41.0 121.0 121.0 6256 (8-40 WELDED firing Doecdption 05inp0_. Stdnp l0-.Tap(00(5) Sot Sop2(1...Sot Dept(TVDI„Stoop Y.L..'Suits-..Stnng Top Tlud ,k` PRODUCTION 612 4.950 40,8 6,258.7 4,244,7 1 (5.50 _ L-80 ABM-EUE 5.5x3.5 Tubing Strings 1 b ..a 6 a L- Tumng Oe.o$paon 5ehg 0... SWrg)D_.Top(1006) se Depth(I...Set Depm(TVO(-.Slang WL.Slemg._String TopT E. TUBING 31/2 2.992 39.3 5,475.8 3,531.1 1 9.30 9-80 ABM-EUE 11. Completion Details Top OepUI Top Ind Naml_. CONDUCTOR Top 1#68) ( ft Item Deuelptlon Comment ID in) 41-I21 39.3 .3 -0.28 HANGER VETCO GRAY HANGER 3.500 5,430.2 3 .7 27.58 NIPPLE CAMCO DS NIPPLE ye 2.812"NO GO PROFILE 2.812 5.475.0 36:530).3 25.665FALASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Del. (rv0) Top ma Tap(IUBI 108.) (( Deee4Mee Comment Run Date ND Iln) j 8,1440 4,139.3 23.29 PLtAh- CIBP.i14fLAUBLS BRIDGE PLUG 5/1(1999 0.000 GAS um t' 5.772 Perforations 8 Slots Shot Top(TYD)Bon(TM Dena 4 Top(1100)atm(MEI) Ild(B) I16(8) Zane 6o (eh_. Type Comment @ 5,580.0 5,612.0 3,025.2 3,054.2 WO D,10.114 '5(3/1995 4.0 IPERF 2.5'NC 311 UJ HMX DP,180 deg F j phase-CLOSED I 5,650.0 5,6780 3,668.6 3,713,9 WS B,10.114 15/3/1999 4.0 IPERF 2.5-HC 3IJ UJ HMX DP,180 deg 8 !APPLE,S,CO N. phase-CLOSED •r', -5,684,0 5,688.0 3,719.43,723.0.0 W5 B,10.114 15/2/1999 4,0IPERF 2.5^HC 31J W HMX DP,180 deg I 8\ 1 phase-CLOSED 5,701.0 5,707,0 3,734.8 3,7402 WS A4.10.114 1512/1999 4.0 IPERF 2.5'HC 3IJ UJ HMX DP,180 deg phase-CLOSED 6717.0 5.722.0 3.749.3 3,753.9 WS A4,10-114 54/1999 4.0 IPERF 2.5-HC3IJ W HMX DP,180 deg 3 phase-CLOSED suLas r. 5,748.0 5.754.0 3,7782 3,783.8 WS A3,10.114 IS/1/1999 40 IPERF 2.5'HC 3IJ UJ HMX DP,I80 5413 T' phase-CLOSED PLUG.}291 ..'".- V 5,776.0 5,781.0 3,803.4 3,807.9 WS A3,10-114 (511/1999 4.0IPERF 2.5'J103I1 UJ HMX DP,180 deg I phase-CLOSED 1 r 5,790.0 5,796.0 3616.1 3,821.5 WS A3,10-114 1511/1999 4,0 IPERF 2.5'HC 3IJ UJ HMX OP,180 deg phase-CLOSES • ) I 5.824.0 5,836.0 3,846.8 3,857.7 WS A2,10-114 9111999 4.0 IPERF 2.5'HC 31J UJ HMX DP,180 deg . prose-CLOSED 5,650.0 5,862,0 3,870.4 3,881,3 WS A2.10-114 1811/1999 4.0 IPERF 2.5'HC 311 UJ HMX DP,180 deg phase-CLOSED Notes:General&Safety Eno Dab Annotation ERF. 1718/2009 !NOTE VERIFY P S A.CEMENT PLUG TESTED 5 2500 PSI ON 1/182009 6_7661571 _ 8/5812010 1NO1E:Yew Schematic w/AJa6Na Satema10.0 PERF. 565}5.578 PERF. 55a4S66E PERF. 51015707 - - 571rWPERF, . i PERF e7a6}J5e PERF, 674 EPF. _ M5 PERP. _ Mandrel Details 65005818 _ Tap Dep1R Top Port (TVD) Incl 0D Valva latch Slot TRO Run Sm Top(MB) LIMB) 0 MVMe I Medal die Sera Typo Typo (In) (psi) Run Date Com, PEP, - 1 5,372.1 3.439.729.60 CAMCO'3,5o1 1 GAS LIFT DMY 1001 6000 0.082711998 68.509 CO2 -- PWO,8H4irill . i PRODUCT. ;.516.• 1 TDx67 ,EV0 I(RU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 1D-114 ConocoPhillips West Sak Injector Proposed P&A Vetco Gray Wellhead System Dry Hole Tree (Post RWO Surface WH Removal) I. II. Ir .a - i (Surface,to 150' I: I I l'j. tt ,E:;,,' l MD P&A I' V 16"62.5#H-40 WLD,121'MD soil' k :,i 1 Cement Plug I 1,= _ :� 4-- —150'MD 5'/:"Casing Leak —►I ; I ; Diesel 1 II 5'/z"x 3'/4"26#J-55 BTC,6,259'MD---�!' Permafrost, f - i�-1,76T MD , g � « I ( 14.8 i �, 1 j t 1 =1 • 1 I ff '' t 1 I 1 I ii+/—/— 5,230'MD Estimated TOC Plug I '+ 1 4 - t 1 . . I 5,372'MD Camco 3-'%"KBG29 GLM .4#r I 5,430'MD Camco 3-'12"DS Nipple L 5,479'MD Baker GBH-22 Seal Assembly and L,, -- J Seal Bole Extension 1 . I 1Y,5-:,"X J'-F'XO iI West Sak Perforations I i 1 5,580.0-5,612.0'MD 5,748.0-5,754.0'MD -«' x- 5,650.0-5,678.0'MD 5,776.0-5,781.0`MD .1'5,684.0-5,688.0'MD 5,790.0-5,796.0'MD y-»z I5,701.0-5,707.0'MD 5,824.0-5,836.0`MD ~1' 5 5,717.0-5,722.0'MD 5,850.0-5,862.0'MD 1 I I I I I 6,144'MD Inflatable Bridge Plug -- ,-- I Data, 24-0et.-2017 I Drawn By; San Makin Page 5 of 5 Loepp, Victoria T (DOA) From: Coberly,Jonathan <Jonathan.Coberly@conocophillips.corn> Sent: Tuesday, February 27, 2018 3:30 PM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R Subject: 1D-114(PTD: 198-159, Sundry:317.504) Attachments: 1D-114 90 day TIO trend 2-27-18.jpg Victoria, In response to the questions earlier today over the phone on 1D-114(PTD: 198-159,Sundry:317.504) I have confirmed the data with the response below. I will submit a change of approved program sundry with this data included. Please let me know if you have questions or concerns. Confirm cement on the backside of the production casing? 1. Primary production casing cement job: a. Pumped 515 bbls 10.5 ppg lead cement&92 bbls 15.8-16.0 ppg tail cement. Saw 10.3 ppg cement returns at surface while pumping lead cement, but ultimately lost returns during tail cement and displacement pumping. Cement Plug barrier justification? 1. Cement plug pumped by displacement method down the tubing: a. 1/14/2009:"ONLINE WITH CEMENT PUMP. 1OBBLS WATER-3BPM,750PSI. 15BBLS 15PPG THIXOTROPIC CEMENT 4.5BPM, 1000PSI. 5BBL WATER 2.5BPM,650PSI. 3OBBL 9.6PPG VISCOSIFIED BRINE 5BPM, 1090P51, 13.4BBL DIESEL 4BPM, 750PSI." b. 1/15/2009: Unable to pass Tubing Mechanical Integrity Test. Plan to pump more cement. c. 1/17/2009: "PUMPING DOWN THE TUBING. 1OBBLS FRESH WATER,27.5BBLS THIXOTRPOIC CEMENT,5BBLS FRESH WATER,28BBLS VISCOSIFIED 9.6PPG BRINE, 13BBLS DIESEL." Estimated cement top as high as 5,230' MD by displacement from 1/14/2009 pump volumes. d. 1/18/2009:Tubing Mechanical Integrity Test to 2,500 psig& Drawdown Test Passed e. 2/5/2018: Tubing Mechanical Integrity Test to 1,500 psig&Drawdown Test Passed 2. Surface pressure history: • a. 2/5/2018: Pressures recorded pre and post MIT-T: Initial T/IA(2 psig/10 psig); Final T/IA(0 psig/10 psig) b. I attached the recent surface pressure history that our Well Integrity folks submit to the AOGCC for the 90 day TIO reporting exercise. Jonathan Coberly Workover Engineering Team Lead ConocoPhillips Alaska,Inc. 700 G Street,ATO 1378 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 1 M Q MSCFD,BLPD PSI a. .c D''Q en CD 000000000 Q to Q N N W1), in 01:11 •14 ip i(7 I-6 O h: A al 00 O N pQj 8-Dec-17 II 8-Dec-17 `-° - 15-Dec-17 15-Dec-17 71 J C ea as O 22-Dec-17 NI r) A 22-Dec-17 co - I29-Dec-17 CI 29-Dec-17 * 5-Jan-18 a 5-Jan-18 ` n o ,a I 12-Jan-18 3 12-Jan-18 W C o .p 7. a I 19-Jan-18 p� s1. 5• 19-Jan-18 a 0 a 2c,-)an-18 c C C 26-Jan-18 m I 2-Feb-18 3 as n r- 1:1 m 0 2- Feb-18 9-Feb-18 9-Feb-18 16-Feb-18 16-Feb-1:E. 23•Feb-18 �3-cP_h-15; v+ '4 w F+ r $ r 0 0 0 0 8 8 degF F a m A -c x 0 rn W 2 13 I d m 13 iiGr z WI rr i F., Loepp, Victoria T (DOA) From: Buck, Brian R <Brian.R.Buck@conocophillips.com> Sent: Friday, November 03, 2017 10:07 AM To: Loepp,Victoria T(DOA) Cc: Heskin, Sara E Subject: • 1D-114 P&A Updates Attachments: 1D-114 P&A Sundry with attachments.pdf Victoria, Thanks so much for your help on this abandonment sundry for 1D-114. Like I said, I'm happy to come over and discuss this if you have any questions regarding the changes. We want to put a cement retainer in the well,as that should allow a better base for a surface cement job and also allow a way to squeeze into the casing leak.We think that change will lead to a better abandonment compared to not having a retainer. That change ended up resulting in a number of tweaks to the procedure,and those are highlighted in red as requested. Look forward to hearing your response. Thank you, Brian Buck Completions and Workover Supervisor office:907-265-6826,cell:907-223-6320,fax:918-662-6213;700 G St.,ATO-1500;Anchorage,AK 99501 scANNED 1,tr rt 1 ri ,' 1 • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska 1D-114 ConocoPhillips West Sak Injector Proposed P&A Vetco Gray Wellhead System Dry Hole Tree (Post RWO Surface WH Removal) 1 I 1 !..-Al '. 1 I I I �y ISurface,to 150" I *; o ' I MD P&A l V 16"62.5#H-40 WLD,121'MDI Cement Plug Ilo. rte,' -t -150'MD 5-1/:"Casing Leak ►I 41 5.1/2"x 3-'/2"26#J-55 BTC,6,259'MD L. Diesel Permafrost, 1,76T MD .9 PPJ fi'. I ,- t . , .47r- 5,230'MD Estimated TOC Plug 1 ., Veir Tt.. 5,372'MD Camco 3-Y2"KBG-29 GLM „t,7„.' 5,430'MD Camco 3-'/2"DS Nipple 104 1 5,479 `, tiO"-�� L J 'MD Baker GBH-22 Seal Assembly and Seal Bore Extension I I I w/543'x 3-54.-x0 1 1 1 ` " 1 I 1 I I West Sak Perforations I 1 �+Ile, ,.- 5,580.0-5.612 0'MD 5 748.0-5.754 0'MD 4 5,650.0-5,678.0'MD 5,776.0-5,781.0'MD _ -4 KO '" 5,6840-5,6880'MD 5790-0-5,796.0'MD . 5,701.0-5.707-0'MD 5,824.0-5,836.0'MD I I 5,717.0-5,722.0MD 5,850.0-5.862.0`MD 1 1 1 44 Ir I ._ 6,144'MD Inflatable Bridge Plug 4 1 I Data: 24-Oct-2017 Drawn By: Sara Realm Page 5 of 5 • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska �,, 3 500292290800ll Attributes KUP SAI< INJ Max 1D-114 �jQ )jjj6r�r.�/ � Well Attributes ax Angle&t WEST *I��..t I YYOIIppre APlMgI ipltl Name Wall Statue Incl l'1 MD 118(81 Act elm(RKB) lI nMRWpp1 2,595.93 6,270.0 -. Comment lin(Pen) Dau Annotation End Date IKR-Grd IM Rig Release Date was 55 Con%-11,110tna6 012111- Au SS5V.NONE Last WO- Il 4641 8125/1998 So- uta-Actual Amobtbn Depth(Rol End Date IAnnotadan Leet Mod-End Date Last Tag: 5.820.0 9/4/2005 Rev Reason:WELL REVIEW osborl 5/22/2012 Casing Strings DANGER 30 lir Casingec Casing Denptian SlA g 0_. String ID-,Top(545) Set Deed,(L..Se Depth(TVD)-.String Wt.:String String Top Tbd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 14-00 WELDED Casing Deecription String Cl.. String ID-,Top(RKS) SW Depth(Let..SDepth(100)..•String Wt-.:Sting..-String Top Tbd 41.-.:41.-.:‘.. b`, PRODUCTION 51/2 4.950 408 6,258.7 4,244.7 15.50 L-90 ABM-EUE 5.5x3.5 Tubing Strings ,.,' c0'4'' ,.,',b: ,, r::..,:° Tubing Deacriphan Seep 0_ String ID_ Top(SOB) SR L.Depth it..Set Oepte(TVD)._I String WString...String Top Th. TUBING 312 2.992 39.3 5.475.8 3,531.1 9.30 L-82 ADM-EUE Completion Details Top Depth flI. (1D/ Top lea Noml... CONDUCTOR _ Top 111481 IRKS) 1•) lam Dereen gon Comment ID lin) 41-Ill 30 3 39.3 -0.28 HANGER VETO)GRAY HANGER 3,500 5,4302 3,490.7 27,58 NIPPLE CALICO DS NIPPLEw/2.812"NO GO PROFILE 2.812 5475.0 3,5303 25.66 SEAL ASSY BAKERGBH-22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) j� rep Sept) 0-vol 'Top incl Too 514a) OBI r) Ceseeesen Comment Run Dna blin) 6.144.C:. 4,139.3. 23.29 PLUG CISP-INFLATABLE BRIDGE PLUG 5.1/1999 0.000 GAS 1_ 5"2 Perforations&Slots ShotTop ego De Top(51,5)ebn(e8) IRt5) MKS) iw,a l)♦N (Win-. type COm,Mn1 5,580.0 5,612.0 3,625.2 3,6542 WS D.10-114 50/1999 4.0(PERE 2.5"HC 3IJ UJ HMX DP,180 leg phase-CLOSED As 5,650.0 5,678.0 3,688.6 3.713.9 WS B,1D-114 5/3,11999 4.0 IPERF 2.5"HC 3IJ W HMX DP,180 deg NPPlE.s 420 ^')� I phase-CLOSED e '�' 5,684.0 5,688.0 3,719.4 3,723.0 WS B,113-114 5/'11999 4.0(PERF 2.5'11C 3IJ W HMX DP,180 deg 8' phase-CLOSED 5,701.0 5.707.0 3,734.8 3,740.2 WS A4,1D-114 ''52/1899 4,0 IPERF 2.5'HC 3IJ W HMX DP.180 deg phase-CLOSED h% 5,717.0 5.722.0 3.749.3 3,753.9 W5 44,1D-114 52/1999 4.0(PERF 2.5"HC 312 W HMX DP,180 dog ' phase-CLOSED SEAL ASSY) „5 5:7480 5,754.0 3.7782 3,783.8 WS A3,10-114 5/1/1999 4.0 PER) 2.5"NC 3IJ UJ HMX DP,180 deg phase-CLOSED PIUG see- 5,776.0 5,781.0 3,803.4 3,807.9 WS 43,10-114 .511/1999 4.0 IPERF 2.5"11C 3IJ W HMX DP,180 deg phase-CLOSED 5,790.0 5,796.0 3,816.1 3,821.5 WS A3,10-114 5/1/1999 4.0(PERE 2.5'HC 3IJ W HMX DP,180 deg phase-CLOSED ' 5,824,0 5,836.0 3,846.8 3,857.7 WS A2,10-114 5/1/1999 4.0 IPERF 2.5'HC 3IJ W HMX DP,180 deg phase-CLOSED 5,850.0 5,862.0 3,870.4 3,881.3 WS A2.1D-114 15/1/1999 4.0 IPERF 2.5"HC 312 W HMX DP,180 deg phase-CLOSED Notes:General&Safety End Date Amato.en PERT. 1(1812009 NOTE VERIFY P 8 A,CEMENT PLUG TESTED @ 2500 PSI ON 1/18/2009 s s60-5612 _ 0)18/2010 NOTE:View Schematic w)Alaska Scherrtatic9.0 PER! 56565/18 - I'1135143 PERF 5.6645666 ' 5141310 mats PERF. r= S P l-5 a7 PERF. Ta a•- 6 7114712 a PERS. PERF, 5776-S731 - -- PERI. Ws= PERF, Mandrel Details 6834-58.38Top Dope, Tap Port _-- (WO) Ina 00 Valve Latch Size TRO Run Sm Top IMO) (MtB) (-1 Make 310d.I ') Into Type Type 0n/ )poi) Run Date Com_. Prop. - 1 5.372.1 3.4397 29.60 CALICO 3.5 z 1 1 GAS LIFT OMY INT 0 000 0.0 8271998 PLUG.6'4.1 jI PRODUCTION r.5a35. 1 41irip , Voi T� y ����y/,- ", THE STATE Alaska Oil and Gas ti ��� ofA /� 1-1 SK ^ Conservation Commission Lj� 333 West Seventh Avenue ; — Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 ' Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Sara Heskin Associate Well Engineer �. F Qr� . ConocoPhillips Alaska, Inc. f ' J P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-114 Permit to Drill Number: 198-159 Sundry Number: 317-504 Dear Ms. Heskin: 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, (12(22 Hollis S. French Chair DATED this day of November, 2017. RBDMS U--N31 - 3 2017 RECEIV7 STATE OF ALASKA OCT 25 21A/ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon U , Plug Perforations H Fracture Stimulate ❑ Repair Well H Operations shutdown Suspend n Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill n Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 198-159' 3.Address: Q 6.API Number: Stratigraphic D Service P. O. Box 100360,Anchorage,Alaska 99510 500292290800 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes ❑ No 2 KRU 1D-114 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 . Kuparuk River Field/West Sak Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,270' ' 4,255' , 1255 5,287',6,144' none Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface Intermediate Production 6,218' 8" 6,259' 4,245' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): From 5,580'to 5,562' From 3,625'to 3,881' 3.500" L-80 5,475' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No packer,no SSSV N/A 12.Attachments: Proposal Summary 0 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑ Service El 1 14.Estimated Date for 1-Nov-17 15.Well Status after proposed work: Commencing Operations: OIL El WINJ n WDSPL I Suspended 16.Verbal Approval: Date: GAS ❑ WAG n GSTOR SPLUG Commission Representative: I GINJ n Op Shutdown I I Abandoned . 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sara Heskin Contact Name: Sara Heskin Authorized Title: ociate Wells Engineer Contact Email: Sara.Heskin@cop.com I ] Contact Phone: (907)265-1027 Authorized Signature: MIX, )2"' Date: I 0 - 24 - l - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ` `"1 Plug Integrity F.V11 BOP Test Ilf'-r Mechanical Integrity Test llLocation Clearance Other: OCIp tis- to ZsPali75-1- 74_, zSG09Si ,4-YJ ✓1 l//a v �J ilt✓r'�n fry is t / 5 4�G-t ce w/71„27-55 et p h a tip c/ ,-„,,, Post Initial Injection MIT Req'd? Yes ri No 4 `2Ofr- c) Spacing Exception Required? Yes n No d Subsequent Form Required: /C — 0.7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I' I �, CK ,\'\ �'� '� �'� /4,41677 ATL � � �, R I G I N A L RBDfv5S Lm - 3 2017 .,_ Submit Form and ,.,, Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • •RECEIVED OCT 2 5 2017 ConocoPh l l i ps AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 1 October 24th 2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 SCANNED Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon (P&A)West Sak injector 1D-114(PTD#: 198-159). 1D-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.MD with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft.MD. In January 2009,a cement plug was pumped to approximately 5,230 ft.MD.as a temporary barrier in preparation for a rig workover to repair the well.The well did not meet economic metrics for a repair and remains suspended for P&A. In October 2015 sundry approval 315-593 was grated to perform an off-rig P&A.Because©ftthe tubing restriction at 145 ft.MD a deeper circulation point for cementing operations could not be established?Per 20 AAC 25.112 well plugging requirements,"Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment." During the off-rig P&A attempt in October 2015 CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft.MD,thus P&A operations were suspended. / CPAI has exhausted all non-rig P&A options and therefore requests sundry approval for an on-rig P&A of 1D-114!The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement.If stretching does not re-gain drift,the tubing will be pulled.44 barrels of kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in.annulus,from the seal assembly to the base of permafrost, prior to pumping a surface cement plug.The surface cement plug will be installed from approximately 145 ft.MD to surface in the IA and tubing,followed by excavation and wellhead removal. The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft.MD.There is 3-1/2 in.tubing to 5,475.8 ft. MD. Ten sets of perforations in the West Sak formation,with the top perforation at 5,580 ft.MD If you have any questions or require any further information,please contact me at 265-1027 or sara.heskin@conocophillips.com. Sincerely, Sank 94eA416*L Sara Heskin Associate Wells Engineer CPAI Drilling and Wells ORIGINAL • �►-'' KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 CURRENT STATUS: 1D-114 is currently shut in under Suspended status with the cement plug isolating the reservoir.This well was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft. KB with a 1.57 in. lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft. KB. In January 2009,a cement plug was pumped to approximately 5,230 ft. KB.as a temporary barrier in preparation for a rig workover to repair the well; However,the well did not meet economic metrics to repair. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A. Due to the tubing restriction at 145 ft. KB a deeper circulation point for cementing operations could not be established. During the off-rig P&A CPAI was unable to obtain confirmation that kill weight fluid remained in the IA.It is believed that the fluid exited the production casing through the leak at 150 ft. MD,thus P&A operations were suspended due to the inability to confirm the fluid barrier.The well has 5-1/2 in.x 3-1/2 in. production casing to 6,270 ft. MD and 3-1/2 in.tubing to 5,475.8 ft. KB. Ten sets of perforations are in the West Sak formation,with the top perforation at 5,580 ft. MD. SCOPE OF WORK: CPAI has exhausted all non-rig P&A options and therefore is planning an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement. If stretching does not re-gain drift,the tubing will be pulled.CPAI intends to cement to surface from as deep as drift access will allow,but at minimum will cement from 145' MD to surface with KWF placed between the existing reservoir cement plug and surface plug.44 barrels of kill weight fluid will be placed in the 5-1/2 in.x3=1/2 in.annulus,from the seal assembly to the base of permafrost.The surface cement plug will be installed from approximately 145 ft. MD to surface in the IA and tubing,followed by excavation and wellhead removal. Well Type: West Sak Single-Casing Injector MPSP: 1255 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,255 psig=(1,600 psig—(0.1 psig/ft*3,441'ND)) Formation Pressure: Max Pressure between Seal Assy.and Base Permafrost—1,600 psi/3,448'TVD Greatest Formation Pressure between Plugs at Time of Abandonment Hydrostatic Calculations: Base of permafrost=1,651.3 ft.TVD(=1,766.8 ft MD) Depth of seal assembly: 5,475.0 ft. MD=3,448.1 ft.ND Maximum pressure between seal assembly and base of permafrost=1,600 psi/3,448'TVD Annulus contains diesel and brine. Assume diesel to base of permafrost: Hydrostaticdiesel =0.354 psi/ft* 1,651 ft.TVD=584 psi KWF=(1,600 psi—584 psi)/(3,448—1,651 ft.TVD)=0.565 psi/ft=10.9 ppg Wellhead Type: Vetco Gray(GE) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/2,500 psig(2,500 psig high for Annular) Integrity Results: Cement Plug Positive&Negative Pressure Tests to 2,500 psi 1/18/09 MIT-T to 2,500 psi 7/1/15 5-1/2"Casing Leak at^'150' MD identified 6/12/08 Earliest Start Date: 1-November-2017 Production Engineers: Pete Fox Workover Engineer: Sara Heskin (907)265-1027 sara.heskin@conocophillips.com Page 1 of 5 • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Proposed Pre-Rig Work: 1. Function-test all T, I.C.,&O.C. LDS. Test tubing, I.C.,&O.C. pack-offs(T-POT/T-PPPOT/IC-POT/IC-PPPOT/ OC-POT/OC-PPPOT).(Completed) 2. Measure T&IA fluid levels. Proposed Rig Workover Procedure: 1. Confirm that an approved sundry has been received from AOGCC. 2. MIRU RWO Rig on well 1D-114. 3. Observe the well for flow for 30 minutes to verify well is static. 4. Install BPV&blanking plug, ND tree, NU BOPE&test to 250/2,500 psi low/high. 5. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat tubing hanger. 6. P/U to stretch the 3-Y2"tubing. 7. R/U wireline to drift tubing,tag top of the cement plug,and punch holes in tubing as deep as possible. a. If top of cement plug is more than 200'from estimated depth contact RWO engineer. b. If the assembly does not drift the obstruction at '150'MD, increase surface overpull in 10% tubing tensile yield limits and attempt to drift tubing. i. If tubing parts,attempt to regain access to tubing. c. Drift tubing and tag TOC.(Estimated at 5,230'MD) d. Punch holes in first full joint above the top of cement,or as deep as possible to create TxIA communication. e. RD Wireline. 8. Circulate through TxIA communication to ensure adequate rate for cementing(+/-2 bpm<=2,000 psi) 9. Load 45 bbls of 10.9 ppg. KWF between the top of the seal assembly and the base of the permafrost in accordance with 20 MC 25.112.(F). 10. RU cement equipment to install surface plug. a. Rig up to pump down the tubing and take returns up the production casing annulus. b. Cement Volume Calculations: i. Volume in tubing=145 ft.x 0.00869627 bbl/ft=1.3 bbl ii. Volume in 3-1/2 in.x 5.5 in.annulus=145 ft.x 0.0119024 bbl/ft=1.7 bbl iii. Excess: 30 bbl iv. Total volume=1.3+1.7+30=33 bbl v. CPAI plans to install cement from the deepest circulation point to surface.At minimum, the plug will be installed 145'MD to surface as outlined in the subsequent steps. c. Pump 3 bbls fresh water spacer and—33 bbls of 15.7 ppg AS Cement. d. If no pressure increase is seen,close IA and squeeze 5-10 bbls of cement.Monitor for pressure increase. Open IA and circulate cement to surface. i. If returns are not to surface after all cement is pumped,displace the tubing volume allowing T x IA circulation point to remain open for repeat job. • Contact RWO engineer to discuss plan forward and notify AOGCC of path forward for repeat cement job. e. RD cement equipment and WOC as per planned slurry&surface sample. Page 2 of 5 • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 11. RU LRS and PT equipment. 12. Pressure test tubing and IA to 1,500 psi.to confirm barriers in place.Record results. 13. Perform drawdown test on tubing and IA to confirm barriers in place. Record results. 14. N/D BOPE, N/U dry hole tree. 15. RDMO RWO Rig. Wellhead Excavation/Final P&A: 1. Remove the Well House(if still installed). 2. Bleed off T/I/0 to ensure all pressure is bled off the system. 3. Remove the production tree,in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found,have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings.AOGCC witness and photo document ✓ required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld%"thick cover plate(16"O.D.)over all casing strings with the following information bead welded into the top. Photo document.AOGCC Witness Required. ConocoPhillips 1D-114 PTD#: 198-159 API #: 50-029-22908-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. 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. Page 3 of 5 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 24th,2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon (P&A)West Sak injector 1D-114(PTD#: 198-159). 1D-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.MD with a 1.57 in.lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft. MD. In January 2009,a cement plug was pumped to approximately 5,230 ft.MD. as a temporary barrier in preparation for a rig workover to repair the well.The well did not meet economic metrics for a repair and remains suspended for P&A. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A.Because of the tubing restriction at 145 ft. MD a deeper circulation point for cementing operations could not be established. Per 20 AAC 25.112 well plugging requirements,"Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment." During the off-rig P&A attempt in October 2015 CPAI was unable to obtain confirmation that kill weight fluid remained in the IA. It is believed that the fluid exited the production casing through the leak at 150 ft.MD,thus P&A operations were suspended. CPAI has exhausted all non-rig P&A options and therefore requests sundry approval for an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement.If stretching does not re-gain drift,the tubing will be pulled.-44-bafr-els-e€Kill weight fluid will be placed in the well and allowed to swap into the 5-1/2 in.x 3-1/2 in.annulus and 3-1/2"tubing below,from the seal assembly to the base of permafrost.Next,a cement retainer will be run at approximately 140'and cement will be squt 'd below the retainer into the suspected casing leak. Then a surface cement plug will be installed from approximately 115 ft. 140'MD to surface in-the I and-tubing, followed by excavation and wellhead removal. The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft.MD.There is 3-1/2 in.tubing to 5,475.8 ft. MD. Ten sets of perforations in the West Sak formation,with the top perforation at 5,580 ft.MD If you have any questions or require any further information,please contact me at 265-1027 or sara.heskin@conocophillips.com. Sincerely, ///J o //�- /LL /-J✓ rS 1�15'c i n Sara Heskin Associate Wells Engineer $�"` Z.001(. CPAI Drilling and Wells ROO a^^ �r„Plc4;d., sh poi 'Sot '2o7-2-10S-442-G5 iii$/ rf • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska CURRENT STATUS: 1D-114 is currently shut in under Suspended status with the cement plug isolating the reservoir.This well was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft. KB with a 1.57 in. lead impression block. Additional diagnostics indicated corkscrewed tubing and a leak in the 5-1/2 in.casing at 150 ft. KB. In January 2009,a cement plug was pumped to approximately 5,230 ft. KB. as a temporary barrier in preparation for a rig workover to repair the well; However,the well did not meet economic metrics to repair. In October 2015 sundry approval 315-593 was granted to perform an off-rig P&A. Due to the tubing restriction at 145 ft. KB a deeper circulation point for cementing operations could not be established. During the off-rig P&A CPAI was unable to obtain confirmation that kill weight fluid remained in the IA. It is believed that the fluid exited the production casing through the leak at 150 ft. MD,thus P&A operations were suspended due to the inability to confirm the fluid barrier.The well has 5-1/2 in.x 3-1/2 in. production casing to 6,270 ft. MD and 3-1/2 in.tubing to 5,475.8 ft. KB. Ten sets of perforations are in the West Sak formation,with the top perforation at 5,580 ft. MD. SCOPE OF WORK: CPAI has exhausted all non-rig P&A options and therefore is planning an on-rig P&A of 1D-114.The tubing will first be stretched in attempt to re-gain drift access to create a circulation point for cement placement. If stretching does not re-gain drift,the tubing will be pulled.CPAI intends to cement to surface from as deep as drift access will allow, but at minimum will cement from 115'^'14( MD to surface with KWF placed between the existing reservoir cement plug and surface plug. '111 barrels of Kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in. annulus,from the seal assembly to the base of permafrost. Next,a cement retainer will be run at approximately 140' and cement will be squeezed below the retainer into the suspected casing leak The surface cement plug will be installed from approximately 145 ft 140' MD to surface in the IA and tubing,followed by excavation and wellhead removal. Well Type: West Sak Single-Casing Injector MPSP: 1255 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,255 psig=(1,600 psig—(0.1 psig/ft*3,441'TVD)) Formation Pressure: Max Pressure between Seal Assy.and Base Permafrost—1,600 psi/3,448'TVD Greatest Formation Pressure between Plugs at Time of Abandonment Hydrostatic Calculations: Base of permafrost= 1,651.3 ft.TVD(=1,766.8 ft MD) Depth of seal assembly: 5,475.0 ft. MD=3,448.1 ft.TVD Maximum pressure between seal assembly and base of permafrost= 1,600 psi/3,448'ND Annulus contains diesel and brine. Assume diesel to base of permafrost: Hydrostaticdiesel =0.354 psi/ft* 1,651 ft.TVD=584 psi KWF=(1,600 psi—584 psi)/(3,448—1,651 ft.TVD)=0.565 psi/ft=10.9 ppg Wellhead Type: Vetco Gray(GE) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/2,500 psig(2,500 psig high for Annular) Integrity Results: Cement Plug Positive& Negative Pressure Tests to 2,500 psi 1/18/09 MIT-T to 2,500 psi 7/1/15 5-1/2" Casing Leak at"'150' MD identified 6/12/08 Earliest Start Date: 1-November-2017 Production Engineers: Pete Fox Page 1 of 4 • KRU 1D-114 Proposed Rig Workover ConocoPh i I l i ps Plug and Abandon Alaska Original PTD#:198-159 Workover Engineer: Sara Heskin (907)265-1027 sara.heskin@conocophillips.com SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Proposed Pre-Rig Work: 1. Function-test all T, I.C.,&O.C. LDS. Test tubing, I.C.,&O.C. pack-offs(T-POT/T-PPPOT/IC-POT/IC-PPPOT/ OC-POT/OC-PPPOT).(Completed) 2. Measure T&IA fluid levels. Proposed Rig Workover Procedure: 1. Confirm that an approved sundry has been received from AOGCC. 2. MIRU RWO Rig on well 1D-114. 3. Observe the well for flow for 30 minutes to verify well is static. 4. Install BPV&blanking plug, ND tree, NU BOPE&test to 250/2,500 psi low/high. 5. Pull the blanking plug&BPV,screw in the landing joint, BOLDS,&unseat tubing hanger. 6. P/U to stretch the 3-Y2"tubing. 7. R/U wireline in an attempt tt drift tubing, tag top of the cement plug, and punch holes in tubing as deep as possible. If successful,attempt to circulate cement through tubing punch. a. If top of cement plug is more than 200'from estimated depth contact RWO engineer. b. If the assembly does not drift the obstruction at —150'MD, increase surface overpull in 10% tubing tensile yield limit`to 40 Klbs and attempt to drift tubing. Do not attempt to part tubing. i. If tubing parts shallower than^'140',attempt to regain access to tubing. ii. If tubing parts deeper than—140',proceed to load the well with 45 bbls of KWF between the top of the seal assembly and the base of the permafrost, attempt a balanced cement plug from deepest point accessible if below suspected leak, then proceed to install a cement retainer, squeeze cement,and pump a surface cement plug. c. Drift tubing and tag TOC.(Estimated at 5,230'MD) d. Punch holes in first full joint above the top of cement,or as deep as possible to create TxIA communication. e. RD Wireline. f. Circulate through TxIA communication to ensure adequate rate for cementing. g. Follow cement with KWF(9.6 ppg). h. RIH with E-line and drift/tag TOC. RIH with E-line string shot and then chem cutter to cut first full joint above TOC. RD E-Line. 8. Assuming the deep drift was not successful, RIH and cut tubing as deep as possible, not in a coupling. Pull out tubing above cut. 9. If drifting past tight spot at"150'was not possibleload well with 50 bbls of 9.6 ppg KWF, and allow fluid to swap to the area between the top of the seal assembly and the base of the permafrost in accordance with 20 AAC 25.112.(F). 10. RIH with 5-1/2" 15.5#casing scraper to 140'. 11. PU, MU and RIH w/cement retainer as deep as possible above where casing is scraped. 12. Set cement retainer.Confirm injectivity by pumping 10 bbls KWF below retainer. Page 2 of 4 • • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Alaska Original PTD#:198-159 13. Rig up cement unit. Squeeze cement into casing leak by pumping 15.7 ppg Arctic Sett cement. Overflush cement retainer by 1 bbl if squeeze pressure not obtained.Repeat cementing operation until squeeze pressure obtained. 14. If squeeze is successful,snap out of cement retainer. Pressure test cement retainer to 1500 psi. 15. Lay in cement on top of the cement retainer on way out of the hole to surface inside 5-1/2" casing, no more than 5' below original ground level. 16, RU cement equipment to install surface plug. Cement Volume Calculations: Volume in tubing- 145 ft.x 0.00869627 bbl/ft- 1.3 bbl Volume in 3 1/2 in.x 5.5 in. annulus- 145 ft.x 0.0119024 bbl/ft-1.7 bbl 8+ Excess: 30 bbl iv- Total volume-1.3+1.7+30-33 bbl a: CPA/plans to install cement from the deepest circulation point to urF ^t mini^um the plug will be installed 145'MD to surface as outlined in the subsequent sfeps e Pump 3 bbls fresh water spacer and-33 bbls of 15.7 ppg AS Cement. If no pressure increase is seen,close IA and squeeze 5 10 bbls of cement.Monitor for Open IA and circulate cement to surface. T x IA circulation point to remain open for repeat job. • . • e - •- • - - . . . . - 'e_ . - for repeat cement job. ent and WOC as per planned slurry Q su face s mpl^ RU LRS and PT equipment. 4$ Pressure test cement to 1,500 psi to confirm barriers in place.Record results. 14- Perform drawdown test en tubing and IA to confirm barriers in plac Record result 20. N/D BOPE, N/U dry hole tree. 21. RDMO RWO Rig. Wellhead Excavation/Final P&A: 1. Remove the Well House(if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings.AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld A"thick cover plate(16"O.D.)over all casing strings with the following information bead welded into the top. Photo document.AOGCC Witness Required. ConocoPhillips 1D-114 PTD#: 198-159 API #: 50-029-22908-00 Page 3 of 4 • • KRU 1D-114 Proposed Rig Workover ConocoPhillips Plug and Abandon Original PTD#:198-159 Alaska 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. 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. • Page 4 of 4 • • ( KUP • 1D-114 ConocoPhillips a Well Attributes Max Angle&MD TD Alaska IIx. Wellbore API/UWI Field Name Well Status Incl(") MD(kKB) Act Bbn(ftKB) 500292290800 WEST SAK INJ 68.25 2,595.93 6,270.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ""• Well Conan-iD-114,5/222012 11:17.48 AM SSSV: NONE Last WO: 48.41 8/28/1998 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 5,820.0 9/4/2005 Rev Reason:WELL REVIEW osborl 5/22/2012 Casing Strings HANGER,30 ' . Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd PRODUCTION 51/2 4.950 40.8 6,258.7 4,244.7 15.50 L-80 ABM-EUE 5.5x3.5 I Tubing Strings Tubing Description String 0... String ID...Top(fIKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 31/2 2.992 39.3 5,475.8 3,531.1 9.30 L-80 ABM-EUE Completion Details Top Depth (TVD) Top incl Nora.. ID(in) 3.500 CONDUCTOR. Top(ftKB) (kKB) (°) Item Description Comment 41-121 39.3 39.3 -0.28 HANGER VETCO GRAY HANGER 5,430.2 3,490.7 27.58 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812 3.000 5,475.0 3,530.3 25.66 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth • (TVD) Top Incl Top(ftKB) (ftKB) ("I Description Comment Run Date ID(in) 6,144.0 4,139.3 23.29 PLUG CIBP-INFLATABLE BRIDGE PLUG 5/1/1999 0.000 GAS LIFT, 5,372 Perforations&Slots Shot Top(TVD) Bbn(TVD) Dens Top(ftKB) Bbn(ftKB) (kKB) OMB) Zone Date (ah,,' Type Comment 5,580.0 5,612.0 3,625.2 3,654.2 WS D,1D-114 5/3/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED 5,650.0 5,678.0' 3,688.6 3,713.9 WS B,1D-114 5/3/1999 4,0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg NIPPLE,5,430 phase-CLOSED 5,684.0 5,688.0 3,719.4 3,723.0 WS B,10-114 5/2/1999 4.0 IPERF 2.5"HC 3IJ W HMX DP,180 deg phase-CLOSED 5,701.0 5,707.0 3,734.8 3,740.2 WS A4,1D-114 5/2/1999 4.OIPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,717.0 5,722.0 3,749.3 3,753.9 WS A4,10.114 52/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED SEAL ASSY, 5,748.0 5,754.0 3,778.2 3,783.6 WS A3,10.114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg s 475 phase-CLOSED PLUG 5 287 5,776.0 5,781.0 3,803.4 3,807.9 WS A3,10.114 5/1/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED Ila 5,790.0 5,796.0 3,816.1 3,821.5 WS A3,10.114 5/1/1999 4.O'IPERF 2.5"HC 3IJ W HMX DP,180 deg phase-CLOSED 5,824.0 5,836.0' 3,846.8 3,857.7 WS A2,10.114 5/1/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED 5,850.0 5,862.0 3,870.4 3,881.3 WS A2,10.114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED Notes:General&Safety End Date _ Annotation IPERF, 1/182009 NOTE:VERIFY P&A,CEMENT PLUG TESTED©2500 PSI ON 1/18/2009 5,580-5,612 8/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF, 5,850-5,678 - IPERF, 5,864-5,888 PERF, 5,701-5,707 IPERF, 5,717-5,722 IPERF, - 5,748-5,754 - IPERF, 5,778-6,781 IPERF, _ ' 5,790-5,706 = IPERF, - - Mandrel Details 5,824-5,038 - Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) P) Mak Model (in) Sow Type Type (in) (PM) Run Date Corn... (PERF, - 1 5,372.1 3,439.7 29.60 CAMCO 3.5 x 1 1 GAS LIFT'DMY INT 0.000 0.0 8/27/1998 5.850-5,862 PLUG,6,144 PRODUCTION 5.5x3.5, TD,6,270 i • 1 D-114 ConocoPh i 1 I i ps West Sak Injector Proposed P&A Vetco Gray Wellhead System Dry Hole Tree (Post RWO Surface WH Removal) I 1 I I I I I I Surface, to I I I Cement I 140' MD P&A 1 1.41- 16" 62.5# H-40 WLD, 121' MD OL i Cement * -00---- -150' MD 5-1/2" Casing Leak 1 1 • • • •• Retainer I .4 5-Y2" x 3-Y2" 26#J-55 BTC, 6,259' MD ; Permafrost, f 1,767' MD 9.6 ppg KWF y 5,230' MD Estimated TOC Plug '` f i •bmeint t I I 11 411 5,372' MD Camco 3-Y2" KBG-29 GLM I f-1 5,430' MD Camco 3-Y2" DS Nipple l II111 I `. { !� J 5,479' MD Baker GBH-22 Seal Assembly and ` " J 1% I Seal Bore Extension _! I I w/5-34'x3-A'X0 I °! 1 I West Sak Perforations I :s.:,, I -. 5,580.0-5,612.0' MD 5,748.0-5,754.0 'MD i 5,650.0-5,678.0' MD 5,776.0-5,781.0 'MD -" 5,684.0-5,688.0' MD 5,790.0-5,796.0 'MD -411 5,701.0-5,707.0' MD 5,824.0-5,836.0 'MD I I 5,717.0-5,722.0 'MD 5,850.0-5,862.0 'MD 1 I II I 1 t� 1 6,144' MD Inflatable Bridge Plug I I Date: 24-Oct-2017 Drawn By: Sara Baskin . y o� T�� • • w �\��j��sA THE STATE Alaska Oil and Gas �, �, of A TAsKA Conservati®n Commissi®n :- Witt_- - 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h:' Main: 907.279.1433 O " Q- T's FALAS , 5 `s - Fax: 907.276.7542 w'i4a ° www.aogcc.alaska.gov 5 Jill Simek 5 Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. \oz.) P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU ID-114 Sundry Number: 315-593 Dear Ms. Simek: 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, a/6fr-e-f-,t-d--- -_, Cathy P.7 . oerster Chair DATED this 84-Clay of October, 2015 Encl. RBDMS)C Oaf d n 2015 STATE OF ALASKA , AL•A OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon i Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown i` Suspend i— Perforate r Other Stimulate r Alter Casing [ Change Approved Program I-- Rug for Redrill ( Perforate New Pool r Repair Well r Re-enter Susp Well r Other: 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory f_ Development f_ 198-159 ' 3.Address: 6.API Number: Stratigraphic E Service y-. P. O. Box 100360,Anchorage,Alaska 99510 50-029-22908-00 . 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes ._ NO l� KRU 1D-114 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25650 - Kuparuk River Field/West Sak 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): 6270 ' 4255 5287, 6144 none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' PRODUCTION 62185.5 6259' 4245' -.yrs ovrn ; X615 / LS Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 5580-5862 , from 3625-3881 3.5 L-80 5476 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program i BOP Sketch r- Exploratory P Stratigraphic 1- Development I- Service w 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2015 OIL I- WINJ i- WDSPL f-` Suspended 1-- 16. -16.Verbal Approval: Date: GAS p WAG i- GSTOR I- SPLUG SPLUG 1- Commission Representative: GINJ r- Op Shutdown 'IJ Abandoned 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263-4131 Email: JiII.Simek(aconocophillips.com Printed Name Jill Si ek 1 Title: Staff Well Integrity Engineer Signature Phone:263-4131 Date 'i / r">� 7 Commission Use Only Sundry Number Q Conditions of approval: Notify Commission so that a representative may witness '�t S" 5 `M Plug Integrity BOP Test r Mechanical Integrity Test r Location Clearance 1" 1\1(.2i-17c-if A-DkGC i'n s/)Ccfor/ pti0to cloefr-�C' t 71C 4'oJ1ata-i Other: /. W`tvf SSS reqs viYet i-o do n F.,‘r 1-7,, ' . t h' si' , e c-, ' r'r-qc .C_ offr-�`o►� t We/ell Yi 2, lN'�t�r55 Cf/t n a 9 ,b lafr 3, .,..i tr C. lc-ar.Gnc-c 4,�pr-cv. Spacing Exception Required? Yes El [� Subsequent Form Required: Iv -- 4 & �(�M APPROVED BY _ Approved by: zie •. o , 3•p . ion is vaffCl iorlI. 0months fr m thT Edgl �r�val. Date:/0-C- lJ 9 / []p 11A Submit Form and Form 10-403 Revised 5/ 0RIGINAL '/L v RBOMS / �tta`c+m nxs ipp licate Viz_ 1 0/1 /15--- /, v4' b 1fUl • • RECEIVED ConocoPhillips SEP 2 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 21 September 2015 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon West Sak well 1D-114(PTD#: 198-159). 1D-114 was originally completed as a single casing West Sak water injector in 1998. In June 2008,a tubing obstruction was encountered and slickline was unable to pass 145 ft.KB with a 1.57 in. lead impression block. Additional diagnostics indicated a leak in the 5-1/2 in. casing at 150 ft.KB. In January 2009,a cement plug was pumped as a temporary barrier in preparation for rig workover. However,the well did not pass the economic hurdles to justify the repair of this single casing injector and the well remains suspended with cement to approximately 5,230 ft.KB. A downhole camera shows curved or corkscrewed tubing at 150 ft.KB,suggesting the well has been damaged by subsidence. Although the well was suspended and cement covers the perforations,continued subsidence increases the chance that a complete plug and abandonment will require a rig. Timely execution of this work will avoid a more costly and higher risk well intervention option. The well has 5-1/2 in.x 3-1/2 in.production casing to 6,270 ft.KB. There is 3-1/2 in.tubing to 5,475.8 ft. KB. Ten sets of perforations are located in the West Sak formation,with top perforation at 5,580 ft.KB Per this procedure,a P&A will be performed by pumping a surface cement plug from approximately 145 ft. KB to surface in the IA and tubing, followed by excavation and wellhead removal. Because of the tubing restriction at 145 ft.KB,a deeper circulation point for cementing operations cannot be established. Per 20 AAC 25.112 well plugging requirements,"Each of the respective intervals of a wellbore between the various plugs must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment." To this end,44 barrels of kill weight fluid will be placed in the 5-1/2 in.x 3-1/2 in. annulus, from seal assembly to base of permafrost,prior to pumping the surface cement plug. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, 25-}f imek e -11 Integrity Engineer CPAI Drilling and Wells • ConocoPhiiiips 1D-114 P&A Permit to Drill #: 198-159 The objective of the proposed 1D-114 P&A is to place kill weight fluid in the 5-1/2 in. x 3-1/2 in. annulus from seal assembly to base of permafrost, then pump a fullbore surface cement plug from approximately 145 ft. KB to surface in the tubing and production casing. Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Little Red Services: Objective: Load 5-1/2 in. x 3-1/2 in. annulus with 10.9 ppg Kill Weight Fluid to base of permafrost Hydrostatic Calculations: • Base of permafrost = 1,651.3 ft. TVD (= 1,766.8 ft MD) • Depth of seal assembly: 5,475.0 ft. MD = 3,448.1 ft. TVD • Maximum anticipated formation pressure between seal assembly and base of permafrost = 1,600 psi Annulus currently holds a combination of diesel and brine. Assume diesel to base of permafrost: • Hydrostaticdiesel= 0.354 psi/ft* 1,651 ft. TVD = 584 psi • KWF = (1,600 psi — 584 psi)/(3,448 — 1,651 ft. TVD) = 0.565 psi/ft = 10.9 ppg Volumetric Calculations: • 5,475.0 ft. MD — 1,766.8 ft. MD = 3,708.2 ft. • 3-1/2" x 5-1/2" Annular Volume = 0.0119024 bbl/ft • Barrels of KWF to be pumped = (3,708.2 ft.)*(0.0119024 bbl/ft) = 44.1 bbls E-line/Little Red Services: Objective: Establish Circulation Point 1. Confirm that an approved sundry has been received from AOGCC. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU E-Line Equipment and PT Lubricator. RU LRS to be able to pump down the tubing, and take returns from IA to tank or accessible flow line. 4. RIH with the 1 in. split shot assembly (utilizing the short 3 ft. x 1 in. E-line weight bars and knuckles) to deepest point possible. NOTE: Based on the recent Slickline drift results, it is assumed that this could be a one way E-line trip, with the 1 in. tools being left downhole when attempting to POOH. 5. If E-line is unable to descend to at least 145 ft. KB, POOH. Call Town Engineer to discuss options. JS • • 6. If E-line is able to descend to or past 145 ft. KB, shoot the 1 in. split shot above the deepest point reached. Reference Tubing Details for correlation. Do not perforate across tubing collar. 7. If E-line is able to shoot the 1 in. split shot, and TxIA circulation is established, circulate 3 bbls of diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 8. RDMO. Well is ready for Fullbore Cement Job. Schlumberger Cementing: Objective: Place a cement plug from —145 ft. KB to surface. We will be circulating cement down the 3-1/2 in. tubing and up the 3-1/2 in. x 5-1/2 in. annulus. NOTE: Cement volume to be discussed and agreed with client representative at site prior to starting cement job, based on actual perforating depth. Cement Volume Calculations: • Volume in tubing = 145 ft. x 0.00869627 bbl/ft = 1.3 bbl • Volume in 3-1/2 in. x 5.5 in. annulus = 145 ft. x 0.0119024 bbl/ft = 1.7 bbl • Excess: 10 bbl • Total volume = 1.3 + 1.7 + 10 = 13 bbl 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU SLB Cement Equipment, ensuring that hardline is rigged up to pump down the tubing and take returns to a tank from the tubing x production casing annulus. 3. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen at surface. 4. PT surface equipment as required. 5. Circulate well to seawater/brine. 6. Pump 3 bbls fresh water spacer. 7. Pump 13 bbls of 15.7 ppg ARCTICSET* 1 (AS1) Cement. a. This calculation assumes 10 bbl of excess cement to ensure good cement to surface. 8. Monitor returns on surface, taking samples and checking pH/density. 9. Once good cement returns are verified on surface (use mud scale for cement density measurement), shut down and open up the surface bypass line to flush all lines with water. 10. Wash up SLB cement pumps. 11. RDMO DHD: 1. WOC 48 hrs. 2. RU LRS and PT equipment. is • • 3. MIT-T with Diesel to 1,500 psi. Record results. 4. MIT-IA with Diesel to 1,500 psi. Record results. 5. Perform drawdown test on tubing and IA. Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld IA" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 1D-114 PTD #: 198-159 API #: 50-029-22908-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. 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 • • Wellbore Schematic: KUP INJ 1D-114 ConocoPhillips \wen Andante*ted Max Angle&MD ID AIaOI(S I c We1oolr APINN't field Name WNlnore Slatufn41`1 MD(TAB) Act Ban lake) 500292290800 WEST SAK WJ 1 69.25 2,595.93 6,2700 Comment MIS(ppm) Data Annotation End Dale XeLrd/IS Rig Release Das 10-+».a+drso+f+xs+ao pM SSSV.NONE LasIWO: 4841 8/28/1998 -- VerosiaaMmam laaWn A+naaoonDepm(a110) End Date AnnoMaon Lan Mod By End Date f�� Last Tag: 5,820.0 9/4/2005 Rev Reason:WELL REVIEW 041/0415/22/2012 4.040.10 3 �i niCasing Strings Casing Defvrodon CDlserlpoon OOOD IIM)I IOD olnont TToIIMnakB) efenl DeDepth 102ke11 fSe+n DeDeapen/R1)VO0T/....,:::::.1.....GGrde TToop TTrtCONDUCTOR 16 15062 410 121 d (2).0 58HWELDED .i PRODUCTION 5 543.5 6 12 4 950 406 6,258.7 4,244 7 15.50 L-80 ABM-EUE . f lig�wu, TubinO uiStnings --.T Wine Deacrlp-on Suing M/2 ID nal row MKS) set 5.4 5 8 sea Depth 11V14 i.2 wt OAR Grede Top connection I TUBING 31(2 2992 392 54758 353)2 930 1-80 ABM-EUEm Completion Details nal m Top Inky) Top ITVD)MOOS) Top MG 111 noun Def Com �IIn1 392 392 000 HANGER VETCO GRAY HANGER 3.500 DONDDC1Oa:•Its-ut.o A 54302 3,4906 27.58 NIPPLE CAMCO OS NIPPLE,N 2612'NO GO PROFILE 2.812 54750 35305 2658 SEAL ASSY BAKER 000-22 LOCATOR SEAL ASSEMBLY 3000 i II Other ho Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top/TOT) Top 0101 Top lhn8) MKS) ('I I Doe I Can I Si.,Date *Pot 6,1440 41393 23.30 PLUG CIBP-*PLAYABLEBRIDGEPLUG 5!1;1999 0.000 PAS LI,PT: Perforations S Slots Snot Das Top(1004 MIP.TOO) Iowan Tep laical &mi0kel (005) peel Ione Dae N Type Com 5,580 0 5,612.0 9625.1 3,654.1 WS D.10-114 543/1999 4.0 PERE 26"HC 3U UJ WAX DP. 180VPhase- C OSED navLs sop 56500 5678.0 3,6885 3,7139 WS B,1D-114 543/1999 40 PERE 2.6'KC 3IJ WHMX DP, Z5180 deg phase r '' CLOSED 5,6840 5,688.0 5,7194 3,723.0 WS B,10-114 5271999 4.0 PERE 25-NC 33.1W MX DP, 180 deg phase- CLOSED 5,701 0 5,407.0 3734 8 3,7402'WS A4,113- 5/2/1999 4 0 WERE 2.5 HC 3U UJ HMX DP. 114 cL180OSdeeggDase ph - E s0A>.ASSY,s.•tsa 5.7170 5,722.0 3,749.3 3,753.9 WS A4,ID- 52/1999 00 WERE 25'HC 3002 HMX DP.. 114 180 deg phase- CLOSED 5748 0 5,754.0 3.777 5 3,783.0 WS 63,10- 511/1999 40 PERE 2.5'HC 3U UJ MAX DP. 114 180 deg phase- CLOSED i. 57760 57810 3,8000 3,8076 WS A3,ID- 6/1/1999 40 PERE -25'NC 3UUJ WAX DP. 114 180OSEde Dhaspe CL 5 790 0 5,7960 3,8167 3,8212 WS A3,1D- 6/111999 40 PERE 2.5'NC 3U UJ inn DP. 114 180 deg phase- CLOSED �faf.saao P.43113.05,824.0 5,8360 3,846.1 3,857.6 WS A2.ID- 541/1999 40 PERE 2.5'NC 3UUJ HMX DP. 114 180 deg phase- CLOSED 5650.0 5,8620 3,8703 3,8813 WS A2,ID- 57111999 40 PERE 26"HC 3U UJ HMX DP, PE..l.0000E.d019 114 160OSEdepDphase- CL Cement Squeezes ,ER,fde•oedtld /op(TVO, Bun(TVb Top 10031 Bon dMP) 1000/ Inky) Des Stan Daa Com 52870 5477.0 33657 35323 PLUG 1/172009 PLUG SET0 TESTED TO 2500 PSI Mandrel Inserts afar 4.1111 61.704.4s, on at Top 0,3e Vat. latch Pon Sae TRO Run N Top In.) 110181 MYe Modal OD IM) dery Type Typo (n) IMI/ Run one Com Paste;4.11,041.11.2.4 I 5.3721 34396 CAMCO 3.5xI 1'GAS LIFT DMY INT 0000 00 8:27/1998 — Notes:General&Safety End Date Annotation O+EW.5.7..134.0 „ 1382009 NOTE.VERIFY P B A.CEMENT PLUG TESTED @ 2506 PSI ON I/182009 - 8/182010 NOTE:View Schematic W Alaska Schemane9.0 •Sar.s,na.o-s.te+a — WERP.S.7.11-41we4 . ■R11.d,edC 444424 nue.al«.o PROGOC TON e4A1gill eaa7 JS • • Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Friday, October 02, 2015 11:50 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1D-114(PTD 198-159, Sundry 315-593) P&A Follow Up Flag: Follow up Flag Status: Flagged Victoria, The plug passed both a positive (2500psi) and negative pressure test on 1/18/2009. Tag was not attempted due to tubing restriction. Jill From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent: Friday, October 02, 2015 11:15 AM To: Simek, Jill Subject: [EXTERNAL]KRU 1D-114(PTD 198-159, Sundry 315-593) P&A Jill, Was the cement plug pumped in January,2009 pressure tested and/or tagged? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeco analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo©alaska.gov 1 • • P&A Diagram: 1D-114 Plug and Abandon PTD#: 198-159 Current Completion Proposed P&A 18"82,5#H-40 Conductor ta 121'KB 4 I Cement Plug TOC Surface 15.7#ARCTICSET 1 'ub^g Punch ig 145 KB 10.9 ppg KWF from 5,475 to 1.757 KB Cement Plug TOC 237 KB{est natedi 3-`4"9.3#L-8. Tubing 5.475.8'KB Seal ly fra 5,475.0'KB CJ0�9 Pens: b� 5,580.0-5.812.0`KB :. 5,550.0-5.878.0'KB 5,884.0-5.888.0"KB 5,717 0-5.707.0"KB1444141441 . 5,717.0-5,722.0'K6 71.111.\\\ 11111111 5,749.0-5,754.0'KB 5,778 0-5,781 0'KB MOM 5,790 0-5,7945.0'KB asme Inlet 5;924.0-5,938.0'KB amp um= mow sem 5,250 0-5,802.0'KB =an INNEE In'latabte Bridge Plug at 0..144.0"KB ..41111 5-14"x 3- Production Casing 8,258.7'KB JS STATE OF ALASKA AL 1CA OIL AND GAS CONSERVATION COIF. .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend well Inspect F. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 19.8-159 3.Address: 6.API Number: Stratigraphic r Service F P 0 Box 100360,Anchorage,Alaska 99510 50-029-22908-00 7.Property Designation(Lease Number) 8.Well Name and Number: ADL 25650 KRU West Sak 1D-114 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10 Field/Pool(s). NA Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary Total Depth measured 6270 feet Plugs(measured) 5287, 6144 true vertical 4255 feet Junk(measured) none Effective Depth measured 6144 feet Packer(measured) 5475 true vertical 4139 feet (true vertical) 3531 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 1640 630 PRODUCTION 6218 8 6259 4245 7000 4990 SCANNED Perforation depth Measured depth: 5580-5862'-Cemented Li�. : 1 �0? RECEIVED True Vertical Depth: 3625-3881'Cemented JUN 3 0 2015 AOGCC Tubing(size,grade,MD,and TVD) 3 5, L-80, 5475 MD, 3531 TVD Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER GBH-22 LOCATOR SEAL ASSEMBLY @ 5475 MD and 3531 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service P Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP P SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt NA Contact MJ Loveland/Martin Walters Email n1878(c�conocophillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature J�//���7,� X Phone:6 43 Date �/ 6/. . ///LS' VTL 714�` RBDMS A-\ JUL - 1 2015 ,'* /4 Form 10-404 Revised 5/2015 Submit Original Only NIPPv ConocoPhillips RECEIVED Alaska JUN 3 0 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit West Sak ID-114 (PTD 198-159) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit West Sak well 1D-114 (PTD 198-159). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well is being held as suspended well until a formal P&A can be completed. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, 477/ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT WSAK 1D-114 Field/Pool: KUPARUK RIVER/WEST SAK Permit# (PTD): 198-159 Sundry 308-452 API Number: 50-029-22908-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 1/14/2009 Surface Location: 46' FNL, 597' FEL Section: 23 Township: 11N Range: 10E Nearest active pad or road: KRU DS1 D Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: none Pits condition: Backfilled Surrounding area condition: Good Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: None Samples taken: none Access road condition: Good Photographs taken (#and description): 3 photos of well and area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Good Rat Hole: NA Wellhouse or protective barriers: Well House Well identification sign: yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: 0 Psi Wellhead Photos taken (#and description): 3 photos of well and area Work Required: None Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: Cody Warfield Inspection Date: 6/27/2015 AOGCC Notice Date: 6/25/2015 Time of arrival: 1455 Time of Departure: 1500 Site access method: Truck y, KUP 1D-114 • ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc ;, Wellbore API/OWI Field Name Well Status Incl(") MD(MB) Act Btm(MB) conolhp:• 500292290800 WEST SAK INJ 68.25 2,595.93 6,270.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••- Well Confi9:-10.174,527201211:1748 AM SSSV: NONE Last WO: 48.41 8/28/1998 Schematic-Actual Annotation Depth(kKB) End Date Annotation Last Mod...End Date Last Tag 5,820.0 9/4/2005 Rev Reason:WELL REVIEW osborl 5/22/2012 Casing Strings Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,39ii pp CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd ,: r PRODUCTION 51/2 4.950 40.8 6,258.7 4,244.7 15.50 L-80 ABM-EUE 5.5x3.5 Tubing Strings i. Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 31/2 2.992 39.3 5,475.8 3,531.1 9.30 L-80 ABM-EUE P Completion Details Top Depth M. 1 (ND) Top not Nomi... CONDUCTOR, Top(MB) (RKB) r) Rem Description Comment ID(in) 41-121 39.3 39.3 -0.28 HANGER VETCO GRAY HANGER 3.500 5,430.2 3,490.7 27.58 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812 5,475.0 3,530.3 25.66 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl ,� Top(kKB) (kKB) (°) Description Comment Run Date ID(in) 6,144.0 4,139.3 23.29 PLUG CIBP-INFLATABLE BRIDGE PLUG 5/1/1999 0.000 GAS LIFT, 5.372 Perforations&Slots = Shot 14 Top(ND) Bier(TVD) Dens Top(RKB)Ban(RKB) (RKB) (MB) Zone Date (ah-- Type Comment 5,580.0 5,612.0 3,625.2 3,654.2 WS D,1D-114 5/3/1999 4.0 IPERF 2.5"HC 3IJ W HMX DP,180 deg iil phase-CLOSED 5,650.0 5,678.0 3,688.6 3,713.9 WS B,10.114 5/3/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg NIPPLE.5.430ii phase-CLOSED 5,684.0 5,688.0 3,719.4 3,723.0 WS B,10.114 5/2/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,701.0 5,707.0 3,734.8 3,740.2 WS A4,1D-114 5/2/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg phase-CLOSED 5,717.0 5,722.0 3,749.3 3,753.9 WS A4,1D-114 5/2/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED SEAL ASSY, 5,748.0 5,754.0 3,778.2 3,783.6 WS A3,1D-114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg 5,475 phase-CLOSED PLUG,5.287 5,776.0 5,781.0 3,803.4 3,807.9 WS A3,10.114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg II phase-CLOSED 5,790.0 5,796.0 3,816.1 3,821.5 WS A3,1D-114 5/1/1999 4.0 IPERF 2.5'HC 3IJ W HMX DP,180 deg phase-CLOSED 5,824.0 5,836.0 3,846.8 3,857.7 WS A2,10.114 5/1/1999 4.0 IPERF 2.5"HC 3IJ UJ HMX DP,180 deg _ _ phase-CLOSED 5,850.0 5,862.0 3,870.4 3,881.3 WS A2,1D-114 5/1/1999 4.0 IPERF 2.5"HC 31J UJ HMX DP,180 deg phase-CLOSED Notes;General&Safety , End Date Annotation IFF:ar - 1/18/2009 NOTE:VERIFY P 8 A,CEMENT PLUG TESTED @ 2500 PSI ON 1/18/2009 5,580-5.612 8/18/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF, 5.6505,678 _ _ IPERF, 5.6845,668 IPERF, -_ 5,701-5,707 t s IPERF. j; 5,717-5,722 „ i IPERF. - 5,7485.754 S->n;a IPERF, 5.7765.781 r-- _Eli M IPERF. _t 5,7905,7% /t IPERF, ,lijib� Mandrel Details 5.8245,836 rg-. --- Top Depth Top --_r_ Port ""`6, -' (ND) Incl 00 Valve Latch Size TRO Run Stn Top(RKB) (RKB) (") Make Model (in) Sery Type Type lin) (psi) Run Date Com... IPERF, -V ' 1 5,372.1 3,439.7 29.60 CAMCO 3.5x 1 1 GAS LIFT DMY INT 0.000 0.0 8/27/1998 5,850.5,962 PLUG.6,144 PRODUCTION 5.5x3.5, 41-6,259 N h TD,6,270 II : r xxg t. cc rr Q J r 00+0 N+ -..± i + N =Q� co n 01 /1 cn0 J. Q 80-0 J CI- II R ' — W o M, at `,_1 Z a d O 113 x Ci 00+Z N+ 1 ":R•' + Ili; — N N // \ . �9 %, RI j w m ciw it A -!it w t.aW Lal o 2 3 a �1 m° 4 ® ° fn ¢ 1! 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P s r 1 ,. .40.1:40,4,„44.„ , ,.,., .4„,. `- ; r3 > , 40. i „z. ,i, ,-(,--„... ...'. 100.70,drbeA° ef 4r04/# r �• g. r ♦r ,y ' .wnM. r �� t jS� ry . 6,4,./.1;Ara: 4,gir, --4.' ' ''' .,.. 4% ',"'-,. WAIKrillig 44.4114 fr fgiifieA, ' `iew rr iiia //it/w4rilai 1 D-114.,PTD 198- fila /// 1I1I 4jwill OConocoPhillips Ala 11/, iiiipji, This photo is co nos, • • • p pY � � 1 I I . . �' I ♦ 1. ConocoPhilli s Alask�r ' p4f,Apik,4?://iiir� � irk cannot bereleased « �• it , without express wilrir 4.,.., ri , :j' • . ►. �. of ConocoPhillip. I,a . 1/i�_. /i ►... t ,".,' ya'�C r • cl ,i ,r yl CD VJ S 11 k d " W f..3 O a o o � � , � � .:4., O > �' O -� a; ". N ; `,E, c a _ ,O N' r • '�- 0 to 730, 0110. , �"' O • r *).,;'..°4:-)- `.•Z) 11108111. 1111 alli illi _ ariiro�a/��a. 1 - �. ' it����1 4 1 , --:-.L.,1 I •. ,., ,. .41 gm no asamo s N �j slammm�i e i 4 ,., 4 v I 4/0110r . ,, ,i, ...,. . ! 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LAT/LONG Onshore/Offshore: Onshore Suspension Date: 01/14/09 Date AOGCC Notified: 06/25/15 Sundry No.: 308-452 • Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 - Photos Taken? Yes IA 0 OA 0 SCANS AUG 1 9 2015 Condition of Wellhead: good and clean/well house was removed due to rig work - Condition of Surrounding Surface Location: good clean gravel , Follow Up Actions Needed: none Comments: celler was back filled Attachments: Photos(3) REVIEWED BY: p r Insp.Supry TPj/E�Nl5 Comm PLB 06/2014 2015-0627_Suspend_KRU_10-114_h.xlsx yA�j 4 A y 1.: ` '.!=,..- - -: .N •,",d' 4 f ''.1.74-'• ..•''• Y.F. t a`4 a. ' eft „ +Y t i Y j Y + {,i. 'S 1 - J.., �, '. Yid-:� '•`', { + '�`♦ lf t SV i +, l R. y s ( t 1,A I (A. et 1-1 • A ,. .o f • ✓ cn�' r �i//ar ,# ,j k i:is s ` rir ,t �ti 04-4 gt+* f of I � :}5. °! ,'. Y Nt ri ;_ gg Q �} aLv r i 'i,... . i 4r ---,. y 4 f . II saa ,Bo t!fit'”,!;' . ¢ ,7 .' 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File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] ' Diskettes, No. [] Other, No/Type 'OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl TO RE-SCAN Notes: ~ ,.~ Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/28/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 1D-114 Oper. Rep: Ian Ives PTD No.: 198 -159 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 01/14/09 Date AOGCC Notified: 08/27/10 Sundry No.: 308 -452 Type of Inspection: Initial Welibore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 - Photos Taken? Yes ' IA 0 ' OA None Condition of Wellhead: Location verified by plot plan. All lines blinded with gauges. Mono bore well. Cellar was dry. Wellhouse was removed for gravel work. Condition of Surrounding Surface The pad looked good. Gravel work was in progress. Location: Follow Up Actions None Needed: Attachments: Photos (2) REVIEWED BY: Insp. Suprvik. 1 Comm • PLB 08/2010 2010- 0828_Suspend_KRU_1 D- 114_bn.xls Suspended Well Inspection — KRU 1D -114 PTD 1981590 Photos by AOGCC Inspector B. Noble 8 -28 -2010 Al . . . , 4 k _� ai .: ., w .. . w • ,e r % � , '_ - - - 1 114 _ ��� • / < < toil%Nnsuu . t \ '° ` 7 . ,, • I . nnnaennn� �.; . '1111111101111111111 , Au u ‘v,NAvax - 4-'12, *,, „ -.,:,,,,,.., ‘:- 4411 AVVVVVVVIVIIII011111 lA INV1VO iVit« � ���� �� ter . 1Htii1i111MIIMI ,Z� lei \., ,. ' 1 KRU 11)-114 Suspended Well Inspection 8 -28 -10 bn ~~ STATE OF ALASKA ~ `~~°~°'~ ®~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Af~~ ~~~009 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1l17~t3iT~ 'a$ Q(~$, ®tti'1ft11SSIQfI Development ~f,~,fyp~~~loratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 14, 2009 12. Permit to Drill Number: 198-159 / 308-452 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 23, 1998 13. API Number: 50-029-22908-00 4a. Location of Well (Governmental Section): Surface: 46' FNL, 597' FEL, Sec. 23, T11 N, R10E, UM 7. Date TD Reached: August 25, 1998 14. Well Name and Number: 1 D-114 Top of Productive Horizon: 2090' FSL, 1858' FWL, Sec. 14, T11 N, R10E, UM 8. KB (ft above MSL): 41' RKB GL (ft above MSL): 71' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2257' FSL, 1630' FWL, Sec. 14, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 6144' MD ! 4139' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560491 y- 5959619 Zone- 4 10. Total Depth (MD + TVD): 6270' MD / 4255' TVD 16. Property Designation: ADL 25650 TPI: x- 557647 y- 5961732 Zone- 4 Total Depth: x- 557417 - 5961897 Zone- 4 11. SSSV Depth (MD + TVD): no SSSV 17. Land Use Permit: 468 18. Directional Survey: Yes ^ No O (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N!A (ft MSL) 20. Thickness of Permafrost MD/TVD: approx. 1766' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drilllLateral Top Window MD/TVD not applicable 23_ CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65.5# H-40 Surf. 121' Surf. 121' 24" 9 cu yds High Early 5.5" 15.5# L-80 Surf. 5477' Surf. 3532' 8.5" 694 sx AS III LW, 470 sx Class G 3.5" 9.3# L-80 5477' 6259' Surf. 4245' 8.5" included above 24. Open to production or injection? Yes ^ No a If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlTVD) 3.5" 5477' none sets of perfs from 5580'-5862' MD 3625'-3881' TVD ` 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ 2009 ~,~ D~ ~~ ~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 5287' 42.5 bbls cement 27, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q Sidewall Cores Acquired? Yes ^ No 0 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 Form 10-407 Revised 7!2009 CONTINUED ON REVERSE ~ Submit original only 28. GEOLOGIC MARKERS (List all formations and marker~ncountered): 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 1776' needed, and submit detailed test information per 20 AAC 25.071. West Sak sand 5578' 3623' West Sak Base 6062' 4064' N/A Formation at total depth: West Sak 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify t the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Na lrJ. Ennis Title: Wells Engineer ~ ~ ~~ Signature Phone 265-1544 Date t~\ Sharon Allsup-Drake y` 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 7/2009 1 D-114 Well Work DATE SUMMARY ~.,; .,,,,,; 1/14/09 BULLHEAD 200 BBLS 9.6 BRI~.~ 4.7 BPM & 1025 PSI. 30 MINUTE SITP 4.,J PSI. PUMP 10 BBLS WTR, 15 BBLS THIXOTROPIC SLURRY 15 PPG AND DISPLACE W/ 5 BBLS WTR, 30 BBLS 9.6 PPG VIS BRINE, 13.4 BBLS DIESEL. SITP 400 PSI. RETURN IN 24HRS FOR PSI TEST. 1/15/09 PRESSURE TEST CEMENT PLUG. TEST FAILED. ABLE TO PUMP INTO THE WELL 2 BPM @ 1000 PSI 1/17/09 SITP 650 PSI. PUMP 10 BBLS WTR, 27.5 BBLS THIXOTROPIC SLURRY 15 PPG AND DISPLACE W/ 5 BBLS WTR, 28 BBLS 9.6 PPG VIS BRINE, 13 BBLS DIESEL. SITP 750 PSI. RETURN IN 24HRS FOR PSI TEST. 1/18/09 Test cement plug to 2500 PSI. Bleed tbg to zero. `,, ~, ~ % KUP ~'"~ 1D-114 ~l7llCf~~~~'fifll~l S ~' , ____ _ _ Max Angle 8 MD i TD ___ Well Attributes AIaSKI. ~I1 C .. ~ .__ Wellbore APUUWI F'eltl N e We115[atu P d Inj Typ 1 I () MD (kKB) Act 6trn (11K8) 500292290800 WEST SAK IINJ ~IPWI ~ 68 25 I 2 595.93 ( 6 270.0 -- Comment H2S (ppm) I - _ Dafe Annotation End Date KB•Grd (k) Rig Release Date I "' 0 SSSV NONE 41 8/28/1998 7/1/2005 Last WO: 48 ~ 11000fjg 10])4 7/~] We " 24091'{ ,51:3@[M ~ _ . k _ ...... . ~__ ~.#- „~e:_ _- _ , -- ` Annotation De th ftKe E d Date An notation End Date Last Ta 5,820 0 9!4/2005 Rev Reason: SHOW CEMENT PLUG 7/21!2009 Casin `'-Strip s - - Str ng O D String ID Set Depth Set D plh (TVD) Strng Wt Strmg _ Casing Description (In) (in) To ~ftKBL (ftKB) ti a-(kKB) (Ibs/ft) Grnde Strip To Thrd ~ - CONDUCTOR 1 _ 6 ~ 15.062 0.0 721.0 121.0 62.58 H-00 Welded coNDUCroR,_ 127 SURFACE 51 _ /2 4.500 _ 0.0 5,477.0 3,532.2 -__.,.._ ~ ~ 75.50 _ L-80 BTC-MOD - PRODUCTION ~3 11 2 2.992 5,477.0 6,259.0 4,245.0 9.30 L-80 EUE-Srd Tubing Strip -- -- - - -- - _ Str ng OD String ID Set D pth Set Depth (ND) Str g Wt Str g Tubin Des<n lion E (I) (in) To ftKB (kKB) (ftKB) (Ibsfft) G de Siring TO Thrd .~___ .._. ._.. ... . 0 ~ ~ _ Tubing _ . 3,532 2 9 30 L-80 EUE-8rd 3 72 2.992 _ O D 5 477. - - - GASUFr,____ ___ 372 - Otherln'Hole A - ll Jewe~;_Tubin Run 8 Retrievable,-Fish _etc) ~ - -- 5, Top Depth (TVD) lop Inc! PLUG, 5,287---- Top B (kKB) (°) Description Comment Run Date ID in) 5,287.0 3,3672 32.54 PLUG CEMENT PLUG TESTED @ 2500 PSI ON 1/78/2009 ' 1/17/2009 0.000 5,372.0 3,439.6 29.60 GAS LIFT _ CAMCO/KBG-2-9/1/DMY/INT/// Comment: STA 1 ~µ~ ~ 8/27/1998 2.900 NIPPLE, 5,430 5,430.0 3,490.5 27.59 NIPPLE CAMCO DS NIPPLEW/NOGO ~ w ~~ ~- 8/27!1998 2.812 5,476.0 3,531.3 25.66 SEAL~~ BAKER GBH-22 LSA ~ ~ __ 8/27/7998 4.000 6,144.0 4,139.3 23.29 PLUG CIBP-INFLATABLE BRIDGE PLUG 5!711999 0.000 Perforations _ __ __ SEAL, 5,476 --------- PLUG, 5,287 Top (N D) Btm (7VD) Shot Dons SURFACE, _._ Top (kKB) Btm (ftKB) (ftKB) (kKB) Zone Date (sh... Type Comment s,a77 5,580.0 5,612.0 3,625.2 3,654.2 WS D, 1 D-114 5/3/1999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 780 deg - phase-CLOSED 5,650.0 5,678.0 3,688.6 3,713.9 WS B, 1D-114 5/3!1999 ~ 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase -CLOSED IPERF, 5,560-s,e1z - 5,684.0 5,688.0 3,779.4 3,723.0 WS B, 7D-114 5/2/1999 4.0 IPERF ~2.5" HC 31J UJ HMX DP, 180 deg - _ - ~ phase-CLOSED 5,701.0 5,707.0 3,734.8 3,740.2 WS A4, 1 D-114 5/2/1999 _ 4.0 IPERF 2.5" HC 31J UJ HMX DQ 780 deg e~... . phase-CLOSED 5 777.0 722.0 5 3,749.3 3,753.9 WS A4, 1D-714 5/2/1999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg IPERF,_-___-__.;, 5,650.5,878 , , ~ phase -CLOSED `- 5,748.0 5,754.0 3,778.2 3,783.6 WS A3, t D-714 5/1/1999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg J phase -CLOSED 5,776.0 5,787.0 3,803.4 3,807.9 WSA3. 1D-114 5/711999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 780 deg - IPERF ~ phase-CLOSED , 5,s6a-s,esa - 5,790.0 5,796.0 3,876.1 3,821.5 WSA3, 1D-114 5/111999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg __ ... phase-CLOSED 5,824.0 5,836.0 3,846.8 3,857.7 WSA2, 1D-714 517!1999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase -CLOSED -- 5,850.0 5,862.0 3,870.4 3,581.3 WS A2, 1 D-114 5!7/1999 4.0 IPERF 2.5" HC 31J UJ HMX DP, 180 deg IPERF. -__ -= phase-CLOSED saol-s,7o7 _ Notes:-:Gene'ral8r'$afet _ ___ - End Date _ __ _ Annotation _ _ 1/18/2009 NOTE: VERIFY P &A, CEMENT PLUG TESTED @ 2500 FSI ON 1/18;2009 IPERF, 5,717.5,722 IPERF, 5,748-5,754 - -' IPERF, _-_ 5,776.5,761 IPERF,___ ..' - 5,790.5,79fi IPERF, _~ 5,824.5,836 ~` ~ w«. ' - IPERF, _ 5,850.5,862 Est ~1 PLUG, 8,144----- PRODUCTION, 6,259 TD, 6,270 Allsup-Drake, Sharon K From: Ennis, J J Sent: Friday, May 22, 2009 2:45 PM To: 'Maunder, Thomas E (DOA)' Cc: Allsup-Drake, Sharon K Subject: 404 for 1 D-114 (PTD 198-159) Attachments: 20090522183247_001. PDF .-,/ 20090522183247_0 01.PDF (196 KB... Tom, This is the well we discussed on phone concerning whether a 404 or 407 was appropriate. We submitted 403 with intention to follow cement plug with rig workover. The rig workover has recently been dropped from our 2009 schedule. Please let Sharon and I know if this 404 is satisfactory. If OK, she'll send it over via normal delivery. Thanks for your help. Have a great weekend! Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 1 • • ~~~ ~ ~ ._~ ~ ~-~ ~ ~~ ~ SARAH PALIN, GOVERNOR COI~SLB~A A,iIOK ~ ~~+~ t.o•••~~•~~~aaaiii~~•iiiiii----777 Oi` 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Engineer ConocoPhillips Alaska Inc. ,-. PO Box 100360 `~~...'~~~~~~'``` ~~~~`~ `. ' ~~~~ Anchorage, AK 99510 ~~j~ ~~ / Re: Kuparuk River Field, West Sak Oil Pool 1 D- 114 Sundry Number: 308-452 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this L, day of December, 2008 Encl. ~p~ STATE OF ALASKA • ~~~~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~`r APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing Q Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-159 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22908-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 1D-114 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 RKB 41', Pad 71' Kuparuk River Field /West Sak Oil Pool ` 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6270' 4255' • 6144' 4139' 6144' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 121' 121' SURFACE 5436' S-1/2" 5477' 3532' PRODUCTION 782' 3-1/2" 6259' 4245' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): f 0 sets of perfs from 5580'-5862' 3625'-3881' 3.5" L-80 5477' Packers and SSSV Type: Packers and SSSV MD (ft) no packer, sealbore extension extension @ 5478 no SSSV 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^~ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat January 12, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the fore of is tr and correct to the best of my knowledge. Contact: Jim Ennis @ 263-1544 Printed Name Jim En IS Title: Wells Engineer Signature Phone 265-1544 Date ] ~ ~' ~ ~ S Commission Use Onl Sundry Number: Conditions of approval: Notify Comm s n so that a representative may witness ~ w O~. Plug Integrity ^ BOP Test ~ Mechanical Integrity Test (~ Location Clearance ^ Other: ~vv~ ~S ~ ~l"~\+~•~~"~~ ~~C9~'l`~~ ~j~ ~~©~~~cvki.lam\~' ~.il'r`'~..C9.'t~t~.V~~~~ Subsequent Form Required: ~~ 1 APPROVED BY ~ ~ ~ ~ ~ (~' b Approved by: COMMISSIONER THE COMMlSSlON Date: Form 10-403 Revised 06/2006. _ ~ .. ,`~ ~?f ~. C~k,f ;1_, ~ ((J(!~i `~ ~ ~ Submit in Duplicate ( ,~ f ~~~~~ tit . !?, ~ • • Rig Workover Sundry Procedure Well 1 D-114 West Sak Injector Replace bent tbg & repair csg .leak Well History and RWO Objective: 1 D-114 was originally completed as a single casing West Sak water injector in 1998. In June, slickline -- was unable to pass a tbg obstruction @ 145' w/ 1.57" LIB. Additional diagnostics indicated a 5.5" csg leak at 150'. Lift gas injection into the csg leak for 30 minutes caused water to begin seeping from the 16" conductor. The wellhas been SI since June and currently has SITP/SICP of 1025/0 psi (8/31/08). Due to the casing leak and wellbore configuration,-only one well control barrier (cmt plug) will exist after the tbg is cut or pulled until a plug can be installed in the casing to mechariically isolate the reservoir or the casing can be filled w/ KWF. The procedure outlined below will TA the West Sak reservoir w/ cement, remove the bent 3.5" tbg, washover the 5.5" casing w/ 9.625" csg, replace bad 5.5" casing, cement both casings to surface and install 2.875" tbg to restore water injection. Pre-Riq Work: Work accomplished to date: 9/24/08 HES ELINE UNIT. ATTEMPT 1" TOOLSTRING BOTTOM HOLE PRESSURE SURVEY.. TAGGING UP ON SOMETHING HARD 6' BELOW MASTER VAVLE. SUSPECT ICE PLUG AND RIG DOWN HES. LATER- RIG UP LRS HOT OIL ABLE TO PUMP 100% MEOH. PUMP 25 BBLS DOWN TUBING. 9/13/08 (PRE-RWO) T-POT-PASSED; T-PPPOT- PASSED; IC-POT -PASSED; IC-PPPOT- PASSED; LDS- FUNCTIONAL 7/30/08 HES VIDEO LOG. LOG VIDEO UTILIZING JUMPERED GAS LIFT GAS. VIDEO APPEARS TO SHOW CURVED OR CORKSCREWED TUBING AT 150'. UNABLE TO PASS WITH 1.69" OD CAMERA. 6/12/08 BLEED IA DOWN TO 0 PSI. 6/11/08 8C LEAK DIAGNOSTICS 6/9/08 ATTEMPTED TO DRIFT W/ 2.02' CENT & 1.75" SAMPLE BAILER. UNABLE TO PASS 145'. RAN 2.70", 2.50", 1.57" LIBs, STILL UNABLE TO PASS @ 1.57". LIBS INDICATE POSSIBLE BUCKLED TBG AT COLLAR (THREAD MARKINGS ON SIDE OF LIB). ..Remaining work: 1. Remove wellhouse and floor kit. Function test LDS's. 2. Bullhead 200 bbls 9.6 ppg brine down tbg @ max rate below 1500 psi TP. Record SITP after 30 minutes & calculate K1NF needed. Freeze protect tbg. Verify IA will -still bleed to zero w/ no flow. 3. RU SLB cementer. Bullhead 10 bbls fresh water down tbg followed by 50 sx thixotropic cement, 5 bbls fresh water, 29.5 bbls viscosified 9.6 ppg brine and 13 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg pressure to zero. 4. Set BPV in the tubing hanger (CIW 3" H) within 24 hours of rig arrival Riq Work: 1. Verify sundry approval for injector casing leak repair. 2. MIRU Nordic #3. Paint line on tree,. tbg head adapter and tbg head. Take photo of tree position for reference at end of workover. 3. Pull BPV. Verify well is dead. Install BPV Jim Ennis Page 1 12/16/2008 • Rig Workover Sundry Procedure Well 1 D-114 West Sak Injector Replace bent tbg & repair csg leak 4. °ND tree. NUBOP. Function test BOP. Pull BPV and install test plug. PT BOP rams to 250/2500. psi and annular to 250/2500 psi. Two month SITP recorded on 8/31/08 was 1025 psi. Amore conservative MASP using this SITP & seawater gradient to top pert (3625' TVD) is 2294 psi. Pull test plug. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) 5. Unland tbg hanger. Attempt to pull tbg from Baker SBE. If unsuccessful @ 80% tbg yield (166M#), rig up E-line and shoot string shot followed by 2.125" chemical-cut of tbg mid-joint as deep as possible w/ string in tension. POOH w/ 3.5" tbg, laying down. No equipment shall leave location until surveyed for NORM. 6. If seals pulled from SBE or chemical cut is below 2000' MD, then go to step #8. 7. If tbg was chemical cut shallow due to tbg restriction, RIH w/ overshot on 2.875" workstring. Engage tbg & work, seals. If unable to pull seals, perform blind backoff to remove damaged tbg. POOH. RIH w/ overshot, engage tbg & work seals. If still unable to pull seats, rig up E-line and shoot string shot followed by 2.125" chemical-cut of tbg mid-joint above seal assembly or as deep as possible w/ string in tension. POOH, laying down 3.5" tbg. 8. RU slickline. Run PDS caliper in 5.5" csg from tbg stub to surface. RD slickline. RIH w/ RBP & Baker fullbore pkr on workstring. Set RBP -50' above 3.5" tbg stub. Set fullbore one joint up & PT RBP to 2500 psi. Release fullbore & locate btm of csg leaks. PT csg & plug below leaks to 2500 psi. POOH. Dump 700# sand (-50') on RBP. 10. NDBOP. Install lokset plug in 5.5" csg one joint down. Cut 5.5" csg w/ MS cutter below wellhead. Remove 5.5" head & hanger. NU diverter stack. 11. Wash over 5.5" csg w/ shoe on 9-5/8" Hydril 511 casing using spud mud to below leaks. Land 9- 5/8" casing a few feet off btm w/fluted hanger on 16" conductor. 12. Wash down to 5.5" lokset plug & POOH. RIH w/ MS cutter and stabilizer to below leak and cut 5.5" csg. POOH. 13. Spear 5.5" csg & POOH laying down. RIH w/ back-off tool & back-off connection below cut. POOH. RIH w/ new 5.5" csg & screw into collar looking up. PT csg 2500 psi. Land 5.5" csg on slips. NU tbg hanger & BOP. PT 5.5" csg & BOP 2500 psi. 14. RIH vv/ 2.875" workstring to below 9.625" shoe. Establish circ w/ hot seawater and continue to circ until cmt reaches 500 psi compressive strength. Establish circ down 9.625" x 5.5" annulus w/ returns through fluted hanger on conductor. Circ cmt down 9.625" csg and back to surface in ,conductor. WOC & continue to circ hot seawater in 5.5" csg. POOH w/ 2.875" workstring. 15. RIH w/ RBP retrieving tool on 2.875" workstring. Reverse circ sand off RBP. Engage & release RBP. POOH- 16. If seal assembly pulled OK, RIH w/ 3.5" completion, drifted to 2.867", as follows: a) Seal assembly w/ locator b) 2.812" Camco `DS' nipple. Jim Ennis Page 2 12/16/2008 • • Rig Workover Sundry Procedure Well 1 D-114 West Sak Injector .Replace bent tbg & repair csg leak c) New 3-1/2", 9.3#, L-80, IBT mod tubing w/ KBMG 1" GLM @5400' RKB (loaded w/ 1500 psi SOV) d) 2.875" Camco `DS' nipple @ 500' (3.5" tbg above must drift 2.91") 17. If tbg was chemical cut, RIH w/ 3.5" completion, drifted to 2.867", as follows:. . e) Baker slick 3.5" overshot f) 2.812" Camco `DS' nipple w/ RHC plug installed g) 1 joint 3.5" tbg h) Baker hydraulic set packer & PBR (pinned 40M# shear) i) New 3-1/2", 9.3#, L-80, IBT mod tubing w/ KBMG 1" GLM @ -5400' RKB (loaded w/ 1500 psi SOV) j) 2.875" Camco `DS' nipple @ 500' (3.5" tbg above must drift 2.91") 18. Locate SBE or tbg stub. Spot corrosion inhibited brine (1 % by volume Baker Petrolite CRW-1.32) in IA below GLM prior to stabbing in/over. If necessary, hang tbg at neutral point, drop ball and rod, set FHL w/ 2500 psi and shear PBR. Space-out for 2' off btm and land tbg hanger with a full joint immediately below. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 30 minutes. Bleed off casing then tubing pressure to zero. `Pressure IA to 2000 psi rapidly to shear SOV. Install BPV. NDBOP. NUWH. Pull BPV. Install test plug. Test tree and packoffs to 5000 psi. Pull test plug. Install BPV. RDMO. Turn well over to Production via Handover Form. Post Rig Work 1. Circ out brine above GLM w/ corrosion inhibited brine (1% by volume Baker Petrolite CRW-132) and freeze protect well w/diesel 2. RU slickline. 3. Replace shear valve with dummy. PT tbg 2500 psi. 4. If necessary, retrieve ball and rod and RHC plug. 5. RU CT. Mill out cmt in tbg/liner to PBTD @ 6163' MD. 6. RU eline. Reperf West Sak zones as before. Jim Ennis Page 3 12/16/2008 --~ KU P ~' Ct?t1t~C(3~11~~1~?5 i` ~~ well Attributes _ >tl,1~*a It` Wellbore APl/UWI F' IdName ' J 500292290800 WEST SA CONDUCTC 1 GAS LII 5,: NIPPLE, 5,4 SEAL, 5,4 SURFA( s,4 IPEF S,SBO-S,E IPEF 5,650.5,E IPEI 5,684-5,E IPEI 5,701-S,i IPEI 5,717-5,i IPEI 5,748-S,i IPEI 5,776-5,i IPEI 5,790-5,i IPEI 5,824-5,F IPEI 5,850-5,F PLUG, 6,1 PRODUCTI( 6,. TD, 6,: _ _• _ 1 D-114 Well S[a[us Ilnclina[ion (`) IMD (ftKB) ~TOtal Depth (ftKB) Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date en c~;~r~ 1e-n4 e~3 xo5 iz eso~am ~ SSSV: NONE 0 7/1/2008 LastWO: 48.41 ,- 8/28/1998 _ , F I ,i _ ~ Annotatlon Depth (ftKB) End Date Annotation End Date Last Tag: I 5,820.0 _ _ 9/4/2005 Rev Reason: TAG OBSTRUCTION @ 143' SLM 6/9/08 8/25/2008 Casin Strings Sel Depth Set Depth (TVD) Wt Casing Descrptlon OD (in) ID (In) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade Top Threatl I CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 Welded ~~ ,~ URFACE 51/2 4.5001 0.0 5,5,477.0 3,532.2 15:50 L-80 - 6TC-MOD _ PRODUCTION 31/21 2.9921 5,477.0 6,259.0 4,245.0 9.30 L-80 EUE-8b Tubing Stringy T' Set Depth (ftKB) b B z Tubing Descrlptlon OD (In) ID (in Top (ftKB) Set Depth (TVD) (ftK ) Wt (l s%t) Grade Top TAread Tubing 31/2 29921 0.0 5,47 0 ~ 3,532.2 9.30 L-80 EUE-8rd _ Other In Hole All Jewelr~r. Tubing Run 8 Retrievable, Fish, etc.) - - - Top (ftKB) Descrlptlon Com ent Run Date ID (in) 5,372.0 GAS LIFT CAMCO/KBG-2-9/1/DMY/INT///Comment: STA 1 8/27/1998 2.900 lu ~ 5,430.0 NIPPLE CAMCO DS NIPPLE W/ NOGG - __ ~~ ~ . 8/27/1998 2.812 5,476.0 SEAL BAKER GBH-22 LSA 8/27/1998 4.000 6,144.0 PLUG Se(Bridge Plug CIBP 5/1/1999 Perforations i s t ,6 e Top (TVD) Ban (TVD) D Top (ftKB) Bbn (ftKB) (ftKB) (ftKB) Type Zone (shot... Date Comment - -- 5,580.0 5,612.0 3,625.2 3,654.2 IPERF WS D, 10.114 4.0 5/3/1999 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5,650.0 5,678.0 3,688.6 3,713.9 IPERF. WS B, 1D-114 4.0 5/3/1999 2.5" HC.31J UJ HMX DP, 180 deg ' phase +- 90 deg orient F, 12 ' 5,684.0 5,688.0 3,719.4 3,723.0 IPERF WS B, 1D-114 4.0 5/2/1999 2.5" HC 31JUJ HMX DP, 180 deg - ', phase +- 90 deg odent 5,701.0 5,707.0 3,734.S 3,740.2 IPERF WS 0.4, 1D-114 4.0 5/2/1999 ' 2.5" HC 31J UJ HMX DP, 180 deg i phase +- 90 deg orient 5,717.0 5,722.0 3,749.3 3,753.9 IPERF WS 0.4, 1D-114 4.0 5/2/1999 2.5" HC 31J UJ HMX DP, 180 deg F phase +- 90 deg odent r6 = '~, 5,748.0 5,754.0 3,778.2 3,783.6 IPERF WS 0.3, 1D-114 4.0 5/1/1999 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5,776.0 5,781.0 3,803.4 3,807.9 IPERF WS 0.3, 1D-114 4.0 5/1/1999 2.5" HC 31J UJ HMX DP, 180 deg phase +- g0 deg orient __ 5,790.0 5,796.0 3,816.1 3;821.5 IPERF WS 0.3, 1D-114 4.0 5/1/1999 2.5".HC 31J UJ HMX DP, 180 deg F, ;6 phase +- g0 deg orient -~- - --- 5,824.0 5,836.0 3,846.8 3,857.7 IPERF WS 0.2, 1D-114 4.0 5/1/1999 2.5" HC 31J UJ HMX DP, 180 deg - phase +- 90 deg orient 5,850.0 5,862.0 3,870.4 3,SSI IPERF WS 0.2, 1D-114 4.0 5/1/1999 2.5" HC 31J UJ HMX DP, 180 deg - - ~ phase +- 90 deg orient _._- )7 - - F. -- rp _- F. F ___ , 37 F. _ 36 6- __ F. __ - . i2 14 -_.~ 0~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 19, 2008 9:46 AM To: 'Ennis, J J' Cc: Eggemeyer, Jerome G. Subject: RE: 1 D-114 (198-159) Thanks Jim. Your comments regarding the BHP and SIWHP are valid. However depending on whether the well is a producer or injector, the operating wellhead pressure may be higher or lower than the SI pressure. A higher value would likely be the case for an injector and in particular one injecting MI. For this well, I stand by the 3000 psi ram test requirement. I agree, there will likely be more messages exchanged on this subject in the new year. Best regards for the holidays. Tom Maunder, PE AOGCC From: Ennis, 7 7 [mailto:7.7.Ennis@conornphillips.com] Sent: Friday, December 19, 2008 9:11 AM To: Maunder, Thomas E (DOA) Cc: Eggemeyer, Jerome C. Subject: RE: 1D-114 (198-159) Good morning Tom, Interesting is one adjective, among others, that definitely applies to 1 D-114. In step #14, the intention is for hot seawater to be circulated in the 5.5" csg beginning before the cement is pumped and continuing through the WOC period at the conclusion of step #14. Sorry for the confusion. If you'd like a 3000 psi BOP test, OK by me but I believe 2500 psi meets state minimum requirements. The only reason I can see for drilling &workover BOP test requirements to be the same is convenience. Typical high long term SITP's for West Sak and Kuparuk are 1000 psi and 2000 psi, respectively. Known BHP &SIWHP values going into a workover along w/ pre-rig MIT's greatly reduce the unknowns encountered during cased hole work as compared to openhole. If we have uncertainty in our BHP values or ops will risk encountering unknown pressures, we typically err on the side of caution and use higher BOP test pressures. I'm sure you'll hear more from us on this topic in the coming weeks. Have a great Christmas! Jim Ennis j j.ennis@conocophiiiips.com (907)265-1544 (VIA (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 18, 2008 4:45 PM To; Ennis, ] 7 Cc: Eggemeyer, Jerome C. Subject: 1D-114 (198-159) Jim, 12/191200$ I am reviewing the woricover procedure for this well. Interesting to say the least!! Page 2 of 2 1. In step 14, I don't follow your comment with regard to circulating until the cement reaches 500 psi compressive strength. At that point, there is no cement in the hole. 2. You also plan a 2500 psi BOP test. The test pressure used when WS wells are drilled is 3000 psi. I believe that is the appropriate test pressure here. 3. Regarding BOP test pressures, I believe it is appropriate to have consistent BOP test pressures for rotary drilling BOPs (20 AAC 25.035) and workover BOPs (20 AAC 25.286) for the pools at Kuparuk. There have been a variety of test pressures proposed in recent work. Some values are lowered due to wellhead limitations. Where there is no limit due to wellhead equipment, based on the recent drilling procedures I have examined, it would appear for a Kuparuk well that the minimum ram test pressure would be 3500 psi and the minimum ram test pressure for a West Sak well would be 3000 psi. Higher BOP test pressures may be appropriate depending on the operating pressures that a well may experience. I would appreciate if you and your drilling colleagues get back to me regarding this. I have copied this to Jerome Eggemeyer as well. Thanks in advance. Tom Maunder, PE AOGCC 12/19/2008 1D-114 (PTD 1981590} Report of IA x Formation communication • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, June 12, 2008 12:05 PM ~l '~- To: " Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1 D-114 (PTD 1981590) Report of IA x Formation communication Attachments: 1 D-114 90 day TI plot.jpg; 1 D-114 schematic.pdf Page 1 of 1 Tom & Jim, West Sak water injector 1 D-114 (PTD 1981590) is suspected to have IA x Formation communication at approxim_ ately 5 '~T~he TI was 975/20 prior to attempting to pressure up the IA . The immediate action was to shut the well in and freeze protect. Diagnostics were performed to confirm the IA x Formation leak at approximately 150'. The well will remain shut in and will most likely require a RWO to repair. Attached is a schematic and a 90 day TI plot. «1 D-114 90 day TI plot.jpg» «1 D-114 schematic.pdf» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~a~~~~~ ~~~ .1 ~~~~ 9/5/2008 KRU 1 D-114 PTD 198-159 T/l/O Plot -1 d-114 1400 1200 1000 800 a. 600 400 200 0 01-Apr-OS 01-Mla~y-08 aat~ 01-J urn-08 200 150 a E 100 d 0 s 50 0 • ~+* ~ ~ KR 1 D-1 U 14 j C~r~ncc~Phi!l~s Alaska, lr~~. """' - - -- 1 D-114 API: 500292290800 Well T e: INJ An le TS: de SSSV Type: NONE Orig 8/28/1998 Angle @ TD: 23 deg @ 6270 Com letion: Gas Lift ~ Annular Fluid: 3% KCI Last W/O: Rev Reason: TAG, PULL PLUG 3ndrel/Dummy _ Reference Lo Ref Lo Date: Last U date: 10/17/2005 Valve 1 (5372-5373, Last Ta : 5820 TD: 6270 ftKB oD:a.725) i ~ Last T_a Date: 9/4/2005 Max Hole An le: 68 de 2596 Tubing Casin Strin -ALL - (o-sari, oD:3soo, Descri tion Size To Bottom TVD Wt Grade Thread iD:2.ssz) Conductor 16.000 0 121 121 62.58 H-40 Welded Production Production 5.500 0 5477 3532 15.50 L-80 BTC-MOD (o-sa77, OD:5.500 Production 3.500 5477 6259 4245 9.30 L-80 EUE-8rd , wt:15.50) Tubin - String - Tubin Size To Bottom TVD Wt Grade Thread 3.500 0 5477 3532 9.30 L-80 EUE-8rd Perforations Summa NiP Interval TVD Zone Status Ft SPF Date T e Comment (sa3o~a31, 5580 - 5612 3625 - 3654 WS D 32 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX DP, OD:3.500) ` 180 deg phase +- 90 deg orient i ~ 5650 - 5678 3689 - 3714 WS B 28 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg ~ orient ', i 5684 - 5688 3719 - 3723 WS B 4 4 5/2/1999 IPERF 2.5" HC 31J UJ HMX DP, !~ 180 deg phase +- 90 deg orient 5701 - 5707 3735 - 3740 WS A4 6 4 5/2/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5717 - 5722 3749 - 3754 WS A4 5 4 5/2/1999 IPERF 2.5" HC 31J UJ HMX DP, seAL ° , 180 deg phase +- 90 deg (5a7s~a77, OD:5 000) ~ ~ orient . 5748 - 5754 3778 - 3783 WS A3 6 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5776 - 5781 3803 - 3808 WS A3 5 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg Production (sa77-szss orient , oD:3.soo, 5790 - 5796 3816 - 3821 WS A3 6 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, wrsso) 180 deg phase +- 90 deg orient Perf - - ____ 5824 - 5836 3847 - 3858 WS A2 12 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, (5580-5612) _ _ 180 deg phase +- 90 deg orient Perf ----- 5850 - 5862 3870 - 3881 WS A2 12 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, (5sso-5676> ~ - 180 deg phase +- 90 deg orient Perf `_ - - ---- . ,.. Gas Lift Mandrels/Valves (5684-5688) ~ ~ - -- - St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv P f !~~ Mfr Run Cmnt er (5701-5707) _ 1 5372 3440 CAMCO KBG-2-9 CAMCO DMY 1.0 INT 0.000 0 8/27/1998 Other lu s, a ui ., etc. -JEWELRY Perf - ------ De th TVD T e Descri tion ID (s717-s72z) 5430 3491 NIP CAMCO DS NIPPLE W/ NOGG 2.812 5476 3532 SEAL BAKER GBH-22 LSA 4.000 Perf 6144 4139 PLUG Set Brid a Plu CIBP 5/1/99 0.000 (5748-5754) Perf -f I (5776-5781) ~-~ _ Perf (5790-5796) _ Perf - (58245836) ~_ Perf (58505862) PLUG (6144-6145, OD:2.992) • SELL L~~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken SuiteW00 7th Avenue ~~~~~~~ ~~~ ~ ~ ~0~~ Anchorage, Alaska 99501 (907) 659-5102 AE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(~a{iper f' MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska, Inc. Pe~trotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and u~~ ~~~-a~Lo ProActive Diagnostic Services, Inc. Attn: Robert A. R~hey 130 West International Airport Road ~ 3 C a9.~ ~ ! s~ Suite C Anchorage, AK 99518 Fax: (907j 245.8951 1) MTT 05~Oct-07 1 i}106 1 Report 50-029-22847-00 2) MTT 05-0ct~07 1 D-114 Signed Print Name: L~t/l(i 5-fr___3 u, 1 V l~ ..r 1 Report 50-029-22908-00 ,~ Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 Fax: (907)245-88952 E-MAIL: Deaga~C~?~^~'~G7eCs~9'TS®9r^pT'/9~~.DS's3 WEB5ITE: ~n~?~J~,~'. „'2~.ye~~'3~~~3.s3~'3 D.\Master_Copy_00_PDSANG20.~cc\Z_Wotd\Distribution\Transmittal_Sheets\Transmit_On~sl_New.doc • • Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhiNips Alaska, lnc. Welt: 1D-114 Log Date: October 5, 2007 Field: Kuparuk Log No.: 8637 State: Alaska Run No.: 2 API No.: 50-029-22908-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 192 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.581b. H-QO Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. L Intvl.: 121 l=t. (MD) Inspection Type : Assess Changes in Corrosive Damage (Metal Loss) to Production Casing. COMMENTS This MTT data is tied into the Mandrel Hanger ~ D' Depth. This is the second log of this weA with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole {70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous {December 8, 2006) indicates a slight increase in metal loss over the intervals from 7' -11' and 16' to 21' as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report. The indication of less metal below the conductor in this log compared to the previous appears to be a calibrations feature rather than metal loss. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (°~) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 16% circumferential meta( loss is recorded in the interval between 13' - 22'. A 10% circumferential metal loss is recorded in the interval between 4' -12'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. tf ail of the metal Ions is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal lass indicated could be from either the 3.5" tubing or 16" conductor. ~Fiefd Engineer. K. Muter Analyst: M. Lawrence & J. Burton Witness: C. Kennedy ~ ProActive Diagnostic Sen,~ices, Inc. / P.U. Box 1369, Stafford, TX 77497 P}ione: {281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS`amemorylog.com Prudhoe Bay Field pfFice Phone; X907) 659-2307 Fax: (907) 659-2314 Comparison to Previou~TT Log Overlay ~~ o~ se~g, ~. October 5, 2007 and December 8, 2006 Database File: d:lwarriorldatal1d-1141comp.db Dataset Pathname: ruNcomp Presentation Format: 24COMP~1 Dataset Creation: Fri Oct 1910:18:06 2007 Charted by: Depth in Feet scaled 1:150 Delta Metal Thickness 2007 -50 Delta Metal Thickness 2006 501 0 Thickness 2006 ~~ 20 30 40 50 60 70 80 90 1 i I Magnetic Thickness T (10 HZ Pass) ~~ n~~~ s~~~ October 5, 2007 Database File: d:lwarriorldatal1d-11411d-114.db Dataset Pathname: run/10hz.2 Presentation Format: 24SCAL~1 Dataset Creation: Fri Oct 1910:33:53 2007 Charted by: Depth in Feet scaled 1:50 -50 Delta Metal Thickness 50 2.4 MTTP01 12.4 0 Line Speed -200 -6.4 MTTP12 3.6 Tree -~ Hanger 5" Collar Pup Jt. J' 10% Metaf Loss 6% Metal Loss 10 3.5" Jt. 1 20 -50 Delta Metal Thickness 50 2.4 0 Line Sneed X00 6.4 MTTP01 MTTP12 12.4 3.6 ConocoPhillips Alaska, Inc. • KRU 1D-114 1D-114 API: 50029229080 0 Well T INJ A le TS: d SSSV Type: NONE Orig 888/1998 Angle @ TD: 23 deg ~ 6270 Com lo tion: Gae LiR Annular Fluid: 3% KCI Last W/O: Rev Reason: TAG PULL PLUG ~ "`~~u"'"y vawe ~ Reference L Ref L Date: Last U ate: 10/17/2005 (5372-5373, Last Ta : 5820 TD: 6270 ftKB o0:a.72s) Last Ta Date: 9/48005 Max Hole An le: 68 d 2596 rurHr~ n ( l,asin Strin -ALL O D:3~50 0; Deacri 'on Size T Botto m TVD Wt Grade Thread i0:z.ss2) Cond uctor 16.000 0 121 121 62.58 H~10 Welded P1°`~On Produ ction 5.500 0 5477 353 2 15.50 L-80 BTC-MOD ~~5 0; Produ ction 3.500 5477 6259 4245 9.30 L-80 EUE-8rd vvt,5.5o) Tu i Strin - Tubin Sine To Bottom ND Wt Grade Thread 3.500 0 5477 3532 9.30 L-80 EUE-8rd Perforations Summa NIP In I ND Z ne S a Ft PF Date T m t (5a30543~, 5580 - 5612 3625 - 3654 WS D 32 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX DP, 00:3.500) 180 deg phase +- 90 deg orient 5650 - 5678 3689 - 3714 WS B 28 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5684 - 5688 3719 - 3723 WS B 4 4 5/2/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +_ 90 deg orient 5701 - 5707 3735 - 3740 WS A4 6 4 5811999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +_ 90 deg orient 5717 - 5722 3749 - 3754 WS A4 5 4 58/1999 IPERF 2.5" HC 31J UJ HMX DP, SEAL (yr7s-5477, l 180 deg phase +. 90 deg o0.5.aoo) - 1 5748 - 5754 3778 - 3783 WS A3 6 4 5/1/1999 IPERF 2. SHC 31J UJ HMX DP, 1 80 deg phase +- 90 deg orient 5776 - 5781 3803 -3808 WS A3 5 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg Production i (5477 szss or ent , 00:3.500, 5790 - 5796 3816 - 3821 WS A3 6 4 5/1/1999 IPERF 2 .5" HC 31J UJ HMX DP, wrs.3o) 1 80 dog phase +- 90 deg orient Pert 5824 - 5836 3847 - 3858 WS A2 12 4 5/1/1999 IPERF 2 .5" HC 31J UJ HMX DP, (55eo-5s~z) 1 80 deg phase+- 90 deg o rient Pert 5850 -5862 3870 - 3881 WS A2 12 4 5/1/1999 IPERF 2 .5" HC 31J UJ HMX DP, (565o-567a) 1 80 deg phase +- 90 deg o rient ''~" G Lift M d l N l (~~ as an re s a ves ) St MD ND Man Men T ype V Mfr ype V T V OD Leboh Port TRO Date Vlv ~„ Mfr Run Cmnt (5701.5707) 1 5372 3440 CAMCO KBG-2-9 CAMCO DMY 1.0 INT 0.000 0 8/27!1998 Other s ui .etc. -JEWELRY Parr D ND T Deac ri ID (5717-s722) 5430 3491 NIP CAMCO DS NIPPLE W/ NOGG 2.812 5476 3532 SEAL BAKER GBH-22 LSA 4.000 Pert 5748 5754 6144 4139 PLUG Set Brid a PI CIBP 5 /1/99 0.000 ( . ) Pert (87765787) Perf (57905798) Pert (5aza5a3s) Perf (58505862) PLUG (61446145, OD:2.992) . . Conoc~illips Alaska RECEIVED .JUL 1 0 2007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 fÎ'" \ sC1 \Ü\~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5~~NED JUL 1 1 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fonn 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement DumDed cement date inhibitor sealant date ft bbls ft Qal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 619/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 61912007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/9/2007 10-119 197-222 2" na 1 6/912007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 10-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 619/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-51 02 ..,(- c ~ C RE : Cased Hole/Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ('". 1 5 '-' {JH ,3t GÜ~iS. 1J 1 Report 2J 1 Report 3J 1 Report 4J 1 Report 5J 1 Report 6J 1 Report 7) Signed: Print Name: 1C-111 MTT Log 1C - 117 MTT Log 1 C - 127 MTT Log 1C - 133 MTT Log 10 - 114 MTT Log 10-117 MTT Log 1 0- Dec -06 u:r Q... êìo I - I d 'ð" 11- Dec -06 UTe.. dOI-18 I 11- Dec -06 U ..lC--.90 1- (I~I 12- Dec 06 U r c... 86l - ó-=t'7 08- Dec -06 U 1" C--lct ~ - (5'ì 09- Dec -06 lJ:IC- l q '7 -éT51- ~.jj~ ~/h(;ØitA-()~ /hi} hv1 ~1/1 Date: If}! IK!()~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAil: :":,,,_,:,'.>:.;"tu;(5J.I.';:_'1:_~'_"_·_':": J-~_>J WEBSITE: j1¡,['P'J,,''';:;,]CR'iL,'>1.':;:;;')¡1 D:\OO _ PDSA1\IC-2006\Z _ W ordlDistributionlTransmittal_ SheetslTransmit_ OriginaLdoc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 10-114 Log Date: December 8, 2006 Field: Kuparuk Log No. : 8077 State: Alaska Run No.: 1 API No.: 50-029-22908-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 192 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log I ntvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum 12% circumferential metal loss is recorded in the interval between 13' - 21'. A 6% circumferential metal loss is recorded in the interval between 4' - 11'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey Witness: C. Fitzpatrick I Analyst: M. Tahtouh & J. Burton i)roActive Diagnostic Services, rne. Phone: (281) or (888) 565-9085 Fax: Prudhoe Bav Fje!d Offlce Phone: PO, Box 1369, Stafford, TX 77497 565..1369 E-mail: PDS@memoryiog.com 6.59-2307 Fax: 659-2314 U IC-.- ~ Cì "ð' -I~~ I I I I I I I I I I I I I I I I I I I <laD. Magnetic Thickness I (10Hz Pass) PR<>AcrIvE l)iAqNOSTlc SER\II"B, INC. Database File: d\warrior\data\1 d-114\1 d-114 db Dataset Pathname: 10hz. 1 Presentation Format: 24SCAL -1 Dataset Creation: Sun Dee 1009:19:162006 by Calc Sondex Warrior VTO Charted by: Depth in Feet scaled 1150 ~Ita Metal Thickness (%)5OT 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftJmin) -200 -6.4 MTTP12 (rad) 3.6 .~.~- tJ .- a - == ._~ - -10 I Tree i I u- -~~-, Hanger 3.5" Collar - 5" Collar Pup Ji. . -- I / l j I , I I I 1= ~- ------ ,l I f F6% Metal Loss 10 4 i ~'i 1 , I "', ~ J I ! - J I- -__.~ '7 ~ I I I ~ 3.5" / i~_/ / I-- 12% Metal Loss Jt. 1 ~ ~ t; I~ I-- I "'-'I , -" I~ 20 I-- I -..... r·" ...... -~'" -- I-- --. 1---- ~~~~- it. . t U~ -~--- r =f '.5" CoII~r- 30 I e--~~~~~~~~ 1---. I ~ Pup Jt. II I 10 3.5" Collal I .5" :::::as! ng Collar Pup Jt. > ---- -~ ---- I 50 i .-. _3.5" 'If I ._-~ --~- I j I i.... I-- FF do...... Line ,Speed I I-- 60 i 3.5" I - c-·;: -- --.... - '-I----- - ,_... Ji. 2 c-~ 1- _n__ I 70 - t =tt I ,u__.__ ._._- ---- -. II ~.om of 1&' Conduct"' ~ 'ot. /1 - ------ I I, 80 ~ 1) ~I -- 3.5" Collar I~ -- J 4 Ij ~~ Ii I I I I I I I I I I I I I I I I I I I I I 1',", I I I I "'- Do- ~ ~ ~ --I f--- 11= ,-5.5" Casin I~ ;S I 90 I-- c-- 1- - - --.... 3_5" ---1- 1---- ^~- --- ----- ---------¡--~ 1---- Jt 3 _m___ f--- ---------- 100 ( , -- -- FEEt I {l ~ I-- 3_ 5" Collar """"A I-- ~- ---- --- f--- ---f--- I-- ---f--- 1~1-- = f--- 120 m~ - E I 3.5" è-- æ - ----- Jt. 4 f--- I .... ~5 5" Casing Collar 130 -- --"Y~- é¡".. ,c-,. [' I ~ ~j-_. ¡ : I ~ 140 ~ 3.5" Collar I I Pì= ~ I I \. 1 I ~ ~ f---' ~ 150 i<' - 3.5" Jt. 5 f--- f-- 160 I-- ------ --- : it- --- i- --- -- --- I--i- ~ ......._...~ ~ -515" Casing Collar 170 I---i- I --- '-- I I ....... 3.5" Collar -- -<; ~ '? - 180 - - - 3_5" ~ I Jt. 6 - -- --I-- ~ I 190 ~ .... I I~ it ~ End of Log- ~--- I : I I I I I I r -50 Delta Metal Thickness (%) 50 24 MTTP01 (rad) 12.4 0 Line Speed (ftlmin) -200 -6.4 MTTP12 (rad) 3.6 I I I I I I I I I I I I I I I I I I I ~ Magnetic Thickness Tool (10Hz Pass) Pm>Ac-rivE Ð!AqNOSYlc SERvicES, INC. Database File: d\warrior\data\1d-114\2'-20' meta! loss\1d-114.db Dataset Pathname: 10hz. 1 Presentation Format: 24SCAL -1 Dataset Creation: Sun Dec 1009:19:162006 by Calc Sonclex Warrior VTO Charted by: Depth in Feet scaled 175 ~ 2.4 MTTP01 (rad) 12.4 -6.4 MTTP12 (rad) 3.6 II~ Hanger I \ I I I 0 3.5" Collar- Pup Jt I 5 5" Collar I . I r·~· I / I' I --r- l !? ] ~~ r· : =-- 1 ) I I~ 1 1 ;; ~.. - 6% Metal Loss l{ { { { Ii i ~ l 10 ~ I . ~- '+ \1 '\ '7~, ." .', 1\1 r 1_- 1 ~ \ - " ~ } IJ ) ~ 1 ,,J 1 J~J- 1/ l/ / ¿:I 1/ } r 1/ / .~.j Il/' ~)" 3.5" j .--~" --- - ..þ t+- 12% Metal Loss Ji. 1 : i . '\ I ! ! I , i 1 .~ ~ "~~ '\1 \'} ptT~ ~ ') .,,~ 1 20 ';> ), 1\ ~I Ii ,¿~ " ," ~ ':¡¡.¡ 1"\ ·iR._ ["""\ .... I"'-;¡ I--~-- f-- f-- I .. \ì:-- I ~ , \ I I I I 1 . I Þ ---- - f-- 1- ... I ! ... I - f--¡ 30 ., 'Wd , r] R; -- --- I I l~ 1 3.5" Collar - I -; Pup Jt. I I . 1 . - ~ ...., _5"¡COIl3¡ W I -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (fUmin) -200 -6.4 MTTP12 (rad) 3.6 I KRU 1 D-114 I I ~ ¡;~ API ~029llW800 Well T "pe: INJ Angle @ TS: dea@ SSSV Type: NONE Orig 8/28/1998 Angle @ TD: 23 deg @ 6270 Completion: Gas Lift Annular Fluid: 3% KCI LastW/O: Rev Reason: TAG, PULL PLUG I ndrellDummy Reference Loa: Ref Log Date: Last Uodate: 10/17/2005 Valve 1 Last Ta¡¡: 5820 TD: 6270 ftKB (5372-5373, OD:4.725) Last T aa Date: 9/412005 Max Hole Angle: 68 deg @ 2596 Tubing v-Al..L (0--5477, Size Top Bottom TVD Wt Grade Thread OD:3.500, n ID:2.992) Conductor 16.000 0 121 121 62.58 H-40 Welded Production Production 5.500 0 5477 3532 15.50 L-80 BTC-MOD (0--5477, Production 3.500 5477 6259 4245 9,30 L-80 EUE-8rd OD:5.500, Wt:15.50) n"u:nm::I"'·· ,Tûbii"la Size 1 Too 1 Bottom I TVD I~I Thread 3.500 1 0 I 5477 I 3532 I L-80 1 EUE-8rd NiP Interval TVO lone Status Ft SPF Date Tvoe Comment (5430--5431, 5580 - 5612 3625 - 3654 WSD 32 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX OP, OD:3.500) 180 deg phase +- 90 deg orient 5650 5678 3689 - 3714 WSB 28 4 513/1999 IPERF 2.5" HC 31J UJ HMX OP, 180 deg phase +- 90 deg orient 5684 - 5688 3719·3723 WSB 4 4 5/2/1999 IPERF 2,5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5701 - 5707 3735 - 3740 WSM 6 4 5/211999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5717 . 5722 3749 - 3754 WSM 5 4 51211999 IPERF 2.5" HC 31J UJ HMX DP, SEAL 180 deg phase +. 90 deg (5476--5477, orient OD:5.000) 5748·5754 3778 - 3783 WSA3 6 4 51111999 IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 5776 - 5781 3803 . 3808 WSA3 5 4 5/1/1999 ¡PERF 2.5" HC 31J UJ HMX DP, Production 180 deg phase +- 90 deg (5477-6259, orient OD:3.500, 5790 . 5796 3816 - 3821 WSA3 6 4 5/111999 IPERF 2,5" HC 31J UJ HMX DP, Wt:9.30) 180 deg phase +. 90 deg orient Perf .---. !-.-- 5824 - 5836 3847 3858 WSA2 12 4 5/1/1999 ¡PERF 2,5" HC 31J UJ HMX DP, (5580--5612) - e--- 180 deg phase +- 90 deg orient Perf - --.- 5850 - 5862 3870 - 3881 WSA2 12 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, (5650--5678) ---- .--- 180 deg phase +- 90 deg orient Perf -..-- IGalti'. (5684-5688) -- St MO ~ Man Type V Mfr I VType I VOD I Latch I Port I TRO I Date I Vlv Per! .-- -- Run Cmnt (5701-5707) --- -.- 1 5372 KBG·2-9 CAMCO I DMY I 1.0 liNT I 0.000 I 0 18/27/19981 I Of her tl=reâl.lilic. Y u:mm:D'V Perf - - . TVDe Description 10 (5717-5722) -- - 3491 NIP CAMCO OS NIPPLE W/ NOGO 2.812 3532 SEAL BAKER GBH-22 LSA 4.000 Perf --- -- 6144 4139 PLUG Set Bridae Plua CIBP 5/1/99 0.000 (5748-5754) ------ -- Per! - - (5776--5781 ) .- - Perf - - (5790--5796) - -- Perf - - (5824-5836) - - Per! - I--- (5850--5862) - I--- PLUG (6144-6145, OD:2.992 ) I I I I I I I I I I I I I I I I MEMORANDUM e TO: Jim Regg -, ¡, P.I. Supervisor K«11 7(Z-Ç'(iX.,:o FROM: JeffJones Petroleum Inspector Well Name: KUPARUK RIV U WSAK ID-1l4 Insp Num: miÚJ06071 I 174248 Rei Insp Num Packer Well i 1D-1I4 ;Type Inj. i W ! TVD P.T. I 1981590 ¡TypeTest i SPT I Test psi Interval 4YRTST P/F P ,// State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHJLLIPS ALASKA INC 1D-114 KUPARUKRIVUWSAK 1D-1I4 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22908-00-00 Permit Number: 198-159-0 1 q'ó -' 15<{ Reviewed By;. P.I. Suprv ,JBJ2- Comm Inspector Name: Jeff Jones Inspection Date: 7/10/2006 1840 1770 15 Min. 30 Min. 45 Min. 60 Min. ~~~~~-- I 1770 Depth 3532 Pretest Initial 1500 I IA I lOA o , Tubing ! I 900 900 900 Notes Monobore injector, 0~9 bbls diesel pumped~ I well house inspected; no exceptions noted~ Wednesday, July 12,2006 900 I ~~-~~ I Page I of I e e KRU 1 D-114 ConocoPhilUps Alaska, Inc. tD-114 Gas lift mdrellDum my Valve 1 (5372~5373 00:4~725) Tubing (0-5477, 00:3~500, 10:2~992) Production (0-5477, 00:5.500, Wt:15~50) NIP (5430-5431, 00:3,500) SEAL (5476-5477, 00:5,000) Production (5477-6259, 00:3,500, Wt9~30) Perf (5580-5612) Perf (5650-5678) Perf (5684-5688) Perf (5701-5707) Perf (5717-5722) Perf (5748-5754) Perf (5776-5781) Perf (5790-5796) Perf (5824-5836) Perf (5850-5862) PLUG (6144-6145, 00:2,992) :«IIB:::::::::::::}:::;::?::::::::: .........,..... ...... :;:;:;:::::;:::::::::::::;:::::::::::;:;:;:;=::::::;:;:;:;: TAG, PULL PLUG 10/17/2005 Thread Welded BTC-MOD EUE-8rd I 5650 - 5678 3689 - 3714 WSB 5684 - 5688 3719 - 3723 WSB 5701 - 5707 WSM SPF ¡Date T e 4 5/3/1999 ¡IPERF 2.5" HC 31J UJ HMX DP, , 1180 deg phase +- 90 deg !orient i 5/3/1999 IIPERF '1'2.5" HC 31J UJ HMX DP, I I 1 ~O deg phase +- 90 deg , onent 4 I 51211999 IPERF ,2~5" HC 31J UJ HMX DP, , 111 ~O deg phase +- 90 deg onent 4 51211999 IPERF 112.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg !orient IPERF 2.5" HC 31J UJ HMX DP, Ii 180 deg phase +- 90 deg onent 4 5/1/1999 IPERF '12.5" HC 31J UJ HMX DP, , 180 deg phase +- 90 deg I ' orient 4 ! 5/1/19991' ¡PERF 2~5" HC 31J UJ HMX DP, I 11 ~O deg phase +- 90 deg ¡ ; ,onent 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP, I 180 deg phase +- 90 deg onent 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient 6 5717 - 5722 3749 - 3754 WSM 5748 - 5754 3778 - 3783 WSA3 5776 - 5781 3803 - 3808 5790 - 5796 3816 - 3821 5824 - 5836 3847 - 3858 5850 - 5862 3870 - 3881 i 4 i 51211999 i 5 6 5 6 Descri CAMCO DS NIPPLE WI NOGO BAKER GBH-22 LSA Set Brid e Plu CIBP 5/1/99 10/07/05 Schlumbepgep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 r.'"'CANNEn Nf1\1 n ') 2005 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ B-. . Ë-o. H'\d '" 't' ð.! ' AUn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk -- Well Job# Log Description Date BL Color CD 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1D-122 11015730 INJECTION PROFILE 09/06/05 1 1C-111 11015732 INJECTION PROFILE 09/22/05 1 10-114 11015728 INJECTION PROFILE 09/04/05 1 2V-08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10102/05 1 1 E-1 05 11015726 TEMPERATURE SURVEY 09/02/05 1 - SIGNED: 1/-JriU DATE: / 7 (\)~Áh- r- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t_ 't r .- J ~'-iil q;; l-t.- MEMORANDUM Chair THRU: Jim Regg ',~ P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 1-D 114, 122, 128, 132 Kuparuk River Unit Kuparuk River Field Packer Depth Pretest Initial 15 Min. 30 Min. w.,,I ~D.,~, I~,.,.i.I ~ I T.v.~. 1~32 I T.~,.oI ~oo I~oo I~oo I~oo I,.t.rva, I 4 P.T.D.I 1981590 Imypetestl p ITestpsil 883 I Casingl 360 I 26201 26001 2600 I P/F I ~ Notes: WellI1D-122 I Typelnj. I SI T.V.D. I ~0 I Tubing I~0 I~,~0 I~,~0 I,~0I lnte~all 4 I P.T.D.I 1981490 IType _ testI P I Testpsil 883 I Casingl POS. I 2500 I 2490 I 2490 I P/FI PI Notes: I WellI1D-128IType,nj.Is I T.V.D. I~ I Tu~i.,I ~oo I ~oo I~oo I~oo I,nte~a,I4 P.T.D.I 1981330 ITypetestl ITestpsil 863 I Casingl 80 I 25001 24901 24901 P/F I E Notes: We,,I 1D-132 IType,,j.I S I T.V.D. I~I T.~i.,I~o I,~o I~o I~o I,nte~a,I 4 P.T.D.I 1981210ITypetestl I Testpsil 872 I Casingl POS. I 25001 24901 24901 P/F I ~ Notes: P.T.D.I Notes: . . Type INJ. Fluid Codes F '- FRESH WATER IN J, G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details As noted in the above report all wells passed. Wall houses were found to be clean and orderly. M.I.T.'s performed: 4 Number of Failures: O Attachments: Total Time during tests: 3 hours CC: MIT report form 5/12/00 L.G. SOANNE~ JUL. 3 1 2003 2003-0620_M IT_KRU_ 1 D- 132_js.xls 7/9/2003 --Well Compliance Rep°rt File on Left side of folder 198-159-0 MD 06270 TYD 04255 Microfilm Roll / - KUPARUK RIV U WSAK 1D-114 50- 029-22908-00 PHILLIPS ALASKA 1NC ietion Date: 3/27/98 Completed Status: 1WINJ Current: Roll 2 / -- Name Interval Sent Received T/C/D D 8762 .~ 1,2 SPERRY MPT/GR/EWR4 OH 10/21/98 10/28/98 L CBL~' FINAL 5400-6100 CH 5 5/6/99 5/19/99 L DGR/EWR4-MD ~ FINAL 121-6270 OH 10/21/98 10/22/98 L DGR/EWR4-TVD ~ FINAL 121-4255 L INJP-PS?c.~ FINAL 5400-6000 1/4/00 OH 10/21/98 10/22/98 CH 5 1/27/00 2/4/00 L SCMT-PSP ,...~' FINAL BL(C) 5400-6140 4/21/99 CH 5 6/8/99 6/16/99 R SRVY RPT ~i"~[ / 7 S~(_.j/~;ERRY7 ~/ 0-6270. OH t/~9/22/98 9/23/98 Daily Well Ops . Are Dry Ditch Samples Required? yes ~ And Rece. i-~ Was the well cormt-~- - Analysis Descriptionq~ece'W~.~-0 Sampl~~ Comments: Tuesday, August 01, 2000 Page 1 of 1 618/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job ii Log Description Date Color Print 2T-210 99240 CBLW/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b.~ c__ 99239 CBT W/PSP/SCMT 990221 1 1C-18 99243 CBT W/PSP/SCMT ~90402 1 1 D- 132 ~ ~ ~__ 99248 SCMT 990216 1 1D- 125 99249 ~BT W/PSP/SCMT 990220 1 1D-114 ~,~ ~ c. 99246 CBT W/PSP/SCMT 990421 1 1D- 128 99247 SCMT 990215 1 1 D- 122 4., ¢ 99244 CBT W/PSP/SCMT 990226 1 1 D- 111 b~ ~ .. 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 /,~ f (.._ 99242 SCMT 990122 1 ,, Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 5/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATI'N: Sherrie NO. 12557 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD-R Print 1D-10 ~ c~-...~,~- 98193 REPROCESSED DSI 980410 1 i 1 1D-111 CBL 990415 1 1 1D-114 CBL 990421 1 1 1 D-132 WFL W/RST 990416 1 1 2B-02 PROD. PROFILE 990423 1 1 3N-18 PROD. PROFILE 990425 1 1 3G-25X 99200 USIT 980107 1 3H-11 99201 USIT 990428 1 , , SIGNED.~~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: J~A~/ '1 c, i999 Alaska Oil & Gas Con~. Com~'ni~io~'~ And'~ora.q~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 6, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-114 (Permit No. 98-159) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D~i 14. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling ORIGINAL TWM/skad - --' STATE OF ALASKA , · ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS E] SUSPENDED E~ ABANDONED~ SERVICE r'~ Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-159 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22908 4 Location of well at surface 9 Unit or Lease Name - i At Top Producing Interval ~_/~.~~/ ';:!F~ ~ 10 Well Number At Total Depth.';:,'~'? ] 11 Field and Pool 2257' FSL, 1630' ~L, Sec. 14, T11N, R10E, UM ';... . . '.' .. '.' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41', Pad 71'~ ADL 25650 ALK 468 ~12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J15 Water Depth, if offshore 16 No. of Completions 23-Aug-98 25-Aug-98 27-Aug-98~ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of pe~afrost 6270' MD & 4255' TVD 6144' MD & 4139' TVD YES ~ NO ~ NA feet MD 1766 APPROX 22 Type Electric or Other Logs Run GR/Res/Neu/Dens 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD I CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT BECOBD 16" 65.58¢ H-40 SURF. 121' 24" 9 cu yds High Eady 5.5' x 15.5¢ L-80 SURF. 5477' 8.5" 694 sx AS III LW & 470 sx Class G 3.5" 9.3~ L-80 5477' 6259' 8.5' (included above) 24 Pedoraflons open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) 58~'-5862' MD 3870'-388]' ~D 5580'-5612' MD 3625'-3654' ~D 3.5" 5476' N/A 5824'-5836' MD 3847'-3858' TVD 5650'-5678' MD 3689'-3714' TVD 5790'-5796' MD 3816'-3821' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5776'-5781' MD 3803'-3808' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5748'-5754' MD 3778'-3783' TVD all 4 spf N/A N/A 5701'-5707' MD 3735'-3740' ~D 5717'-5722' MD 3749'-3754' TVD 5684'-5688' MD 3719"-3723' TVD 27 PRODUCTION TEST Date First Production Method of Operationlnjector(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOI ' Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. West Sak Sand 5578' 3623' West Sak Base 6062' 4064' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig ned Title DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/26/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-ii4 WELL ID: AK9589 TYPE: AFC: AK9589 STATE:ALASKA 22908-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/23/98 START COMP: RIG:RIG % 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029- 08/17/98 (D1) TD: 121' (121) SUPV:FRED HERBERT MW: 0.0 VISC: RIG MAINTENANCE 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from 1D-122 to 1D-114. Accept rig @ 1400 hrs. 8/17/98. Move rig to 1D-123. 08/18/98 (D2) TD: 121'( 0) SUPV:DON E. BREEDEN MW: 0.0 VISC: RIG MAINTENANCE 0 PV/YP: 0/ 0 APIWL: 0.0 Continue with rig maintenance. Wash and clean top drive. 08/19/98 (D3) MW: 0.0 riSC: TD: 121' ( 0) RIG MAINTENANCE SUPV:DON E. BREEDEN & MOOSE CUNNING Continue rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 08/20/98 (D4) MW: 0.0 VISC: TD: 121' ( 0) RIG MAINTENANCE SUPV:DON E. BREEDEN & MOOSE CUNNING Continue rig maintenance. 0 PV/YP: 0/ 0 APIWL: 0.0 08/21/98 (D5) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD: 121' ( 0) RIG MAINTENANCE SUPV:DON E. BREEDEN & MOOSE CUNNING Continue with rig maintenance. APIWL: 0.0 08/22/98 (D6) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 121' ( 0) BOPE TEST,MIX SPUD MUD, ESTIMATED SPUD @ 0700 SUPV:DON E. BREEDEN & MOOSE CUNNING Finish rig maintenance. Move utility module. NU 21.25" annular. 08/23/98 (D7) MW: 9.6 VISC: 221 PV/YP: 39/47 APIWL: 5.4 TD: 2463' (2342) MAKING 8 1/2 "HOLE SUPV:DON E. BREEDEN & MOOSIE CUNNIN NU diverter and function test. Drill from 121' to 2463' Date: 1/26/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/24/98 (DS) MW: 9.6 VISC: 235 PV/YP: 42/60 APIWL: 6.2 TD: 5100' (2637) MAKE 8.5" HOLE SUPV:MOOSE CUNNINGHAM/DON E. BREEDE Make hole 8.5" from 2463' to 2463'. Wash from 1440' to 1665'. Wash and ream from 2185' to 3602'. Make hole from 3602' to 5100' 08/25/98 (D9) TD: 6270' (1170) SUPV:DON E. BREEDEN MW: 9.7 rISC: 188 PV/YP: 46/52 PREPARE TO RUN CASING APIWL: 4.4 Drill from 5100' to 6270'. Circulate low-visc sweep around. Pump slug. POH. Some swabbing in places. RIH w/hole opener. Some bridges or ledges below 4300' Wash & ream to bottom at 6270' 08/26/98 (D10) TD: 6270'( 0) SUPV:DON E. BREEDEN MW: 9.6 VISC: 74 PV/YP: 26/29 TEST BOPE Run 5.5"x 3.5" casing. APIWL: 5.5 08/27/98 (Dll) TD: 6270' ( 0) SUPV:DON E. BREEDEN MW: 8.7 VISC: RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 ND diverter. NU BOPE and test to 300/3000 psi. Run 3.5" completion. ND BOPE. NU tree. 08/28/98 (D12) TD: 6270'( 0) SUPV:DON E. BREEDEN MW: 8.7 VISC: RIG RELEASED 0 PV/YP: 0/ 0 NU tree. Release rig @ 0300 hrs. 8/28/98. APIWL: 0.0 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~, K1 (1D-114(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-114 DRILLING SUPPORT-CAPITAL 0321992053.12 DATE DAILY WORK UNIT NUMBER 05/01/99 SET CIBP/PT WELL / PERF 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 NO YES SWS-ELMORE KOLSTAD FIELD AFC# CC# Signed ESTIMATE AK9589 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 550 PSI 100 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY SET BAKER CIBP AT 6144'- PRESSURE TEST WELL BORE AT 1800 PSi FOR 30 MIN - GOOD TEST - PERF 5850'-5862' & 5824'- 5836' & 5790'-5796' &5776'-5781' & 5748'-5754' W/2.5" HC 31J UJ DP/4 SPF/180 DEG PHASING ORIENTED +/- 90 DEG [MIT, Perf] TIME LOG ENTRY 08:15 MIRU SWS 08:45 TG SAFETY MEETING 09:00 RIH W/BAKER CIBP/CCI_/6' X 2 1/8" WEIGHT BAR/ROLLERS ON TOP 09:30 CIBP GOING DOWN HOLE SMOOTHLY AT 80-90 FT/MIN 10:00 TIE IN TO JEWELRY 10:19 SIT DOWN AT 6162'- FINISH TIE IN 10:30 TAG PROFILE AT 6162'- PULL UP TO SEE TENSION PICK UP TOOL STRING WEIGHT ON LOG - SET CIBP AT 6144' - TENSION DROP - WAIT FOR ELEMENT TO EXPAND - LOG UP TO CHECK DEPTH - SET BACK DOWN ON BRIDGE PLUG AT 6144' AND STACK IN 5' OF CABLE 10:50 PULL UP HOLE TO ABOVE JEWELRY - PRESSURE UP TUBING TO 1@20 PSI FOR STATE INTEGRITY TEST 10:50 START OF TUBING MIT - WHP=1820 PSI 11:00 WHP=1800 PSI 11:10 WHP=1775 PSI 11:20 WHP=1775 PSI - WELL LOST < 10% OF INITIAL PRESSURE IN 30 MIN - GOOD TEST 11:30 BLEED DOWN PRESSURE AND POOH 12:00 OOH - PU AND RIH W/2.5" X 20' GUN HC 31J UJ DP/4 SPF/I$0 DEG PHASING ORIENTED +/- 90 DEG - ROLLERS TOP AND BOTTOM/6' X 2 1/8" WT BAR/CCL - ONLY BOTTOM 12' OF GUN LOADED 12:40 TIE IN - PERF 5850'-5862' - TENSION DROP - LOG UP - NO CHANGE IN WHP - POOH TIME 13:20 14:05 14:30 15:15 LOG ENTRY OOH - ALL SHOTS FIRED - PU 20' GUN W/BOTTOM 12' LOADED/ROLLERS TOP AND BOTTOM/6'X 2 1/8" WT BAR/CCL - RIH - NO PROBLEMS GETTING DOWN TIE IN - PERF 5824'-5836' W/2.5" HC 31J UJ DP/4 SPF/180 DEG PHASING ORIENTED +/- 90 DEG - TENSION DROP- LOG UP- POOH OOH - ALL SHOTS FIRED - PU 20' GUN LOADED TOP 5'/9' BLANK SECTION/BTM 6' LOADED - SAME ROLLER AND WT CONFIGURATION - RIH PERF 5790'-5796' & 5776'-5781' W/2.5" HC 31J UJ DP/4 SPF/180 DEG PHASING ORIENTED +/- 90 DEG - TENSION DROP - LOG UP- POOH 15:50 OOH - ALL SHOTS FIRED - PU 10' GUN W/BTM 6' LOADED - RIH W/SAME TOOL CONFIGURATION 16:30 TIE IN 16:40 PERF 5748'-5754' W/2.5" HC 31J UJ DP/4 SPF/180 DEG PHASING ORIENTED +/- 90 DEG - TENSION DROP - LOG UP- WHP= 100 PSI - POOH 17:10 OOH - ALL SHOTS FIRED 18:00 RDMO SWS ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,~' K1(1D-114(W4-6)) .. WELL JOB SCOPE JOB NUMBER 1D-114 DRILLING SUPPORT-CAPITAL 0321992053.12 DATE DAILY WORK UNIT NUMBER 05/02/99 PERFORATE 5701-5707', 5717'-5722', & 5684'-5688'. 2128 DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 5 NOI YES SWS-ELMORE ODELL FIELD AFC# CC# Signed ESTI MATE AK9589 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 500 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED 5701'-5707', 5717'-5722', & 5684'-5688', 2-1/2" HOLLOW CARRIERS, 4 SPF, 180 DEG PHASE, +/- 90 DEG ORIENTATION, DEEP PENETRATING, TIME LOG ENTRY 13:30 SWS ARRIVE ON LOCATION FROM 1L-03, RU. 15:00 PT LUBTICATOR TO 300 PSI, MAKE UP GUN. 2-1/2" HOLLOW CARRIER, 4 SPF, 180 DEG PHASING, +/- 90 DEG ORIENTATION, 31J UJ DEEP PENETRATING CHARGES. 15:30 RIH 16:00 ON BOTTOM, MAKE TIE-IN PASSES. 16:10 PARK GUN TO SHOOT 5701' - 5707' AND 5717' - 5722'. SHOOT GUNS, GOOD INDICATION AT SURFACE. LOG UP, POOH 16:35 OOH, ASF. MAKE UP GUNS. 2-1/2" HOLLOW CARRIER, 4 SPF, 180 DEG PHASING, +/- 90 DEG ORIENTATION, 31J UJ DEEP PENETRAING CHARGES. 16:50 RIH 17:20 ON BOTTOM, MAKE TIE-IN PASSES. 17:25 PARK GUNS TO SHOOT 5684'- 5688'. SHOOT GUNS, GOOD INDICATION AT SURFACE. LOG UP, POOH. 18:00 OOH, ASF 18:10 RDFN. 19:15 SWS RIGGED DOWN, WELL SECURED. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~, K1 (1D-114(W4-6)) WELL JOB SCOPE JOB NUMBER " 1 D-114 DRILLING SUPPORT-CAPITAL 0321992053.12 DATE DAILY WORK UNIT NUMBER 05/03/99 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 YES YES SWS-ELMORE ODELL FIELD AFC# CC# Signed ESTI MATE AK9589 18WSTF7S C InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 500 PSI 500 PSI 0 PSI 0 PSIIlo PSI 0 PSI DAILY SUMMARY PERFORATED 5580'-5612' AND 5650'-5678', 2-1/2" HOLLOW CARRIERS, 4 SPF, DEEP PENETRATING, 180 DEG PHASING, +/- 90 I DEG ORIENTATION. MEASURED STATIC BOTTOMHOLE PRESSURE 1596 PSi AT 5721' (MID PERFS).[Perf, Pressure Data] I TIME LOG ENTRY 07:00 SWS ON LOCATION, RIG-UP. TAILGATE SAFETY MEETING. 07:30 GO TO RADIO SILENCE, MAKE UP GUN, PT LUBRICATOR TO 3000 PSI. 08:00 RIH W/CCL/PERF GUN. 28' GUN, 2-1/2" HOLLOW CARRIER, 4 SPF, DEEP PENETRATING 31J UJ HMX DP CHARGES, 180 DEG PHASING, +/-90 DEG ORIENTATION. CCL TO TOP SHOT = 8'. 08:50 ON BOTTOM, MAKE TIE-IN PASSES. 09:05 PARK CCL AT 5642', GUNS AT 5650'-5678'. SHOOT GUNS, GOOD SURFACE INDICATION. LOG UP, POOH. 09:35 CCH, ASF. MAKE UP 20' GUN, SAME CHARGES AND ORIENTATION. 10:30 RIH W/20' GUN. 11:05 ON BOTTOM, MAKE TIE-IN PASSES 11:08 PARK CCL AT 5587.5', 4.5' CCL TO TOP SHOT, GUNS AT 5592'-5612'. SHOOT GUNS, GOOD SURFACE INDICATION. LOG UP, POOH. 11:35 CCH. ASF. MAKE UP 12' GUN, SAME CHARGES AND ORIENTATION. 12:00 RIH W/12' GUN. 12:25 ON BOTTOM, MAKE TIE-IN PASSES. 12:35 PARK CCL @ 5567.5', CCL TO TOP SHOT = 12.5', GUNS AT 5580'-5592'. SHOOT GUNS, GOOD SURFACE INDICATION. LOG UP, POOH. 13:05 CCH, ASF. PICK UP CCL/GRFFEMP/PRESS TOOL FOR SBHP. 13:15 RIH FOR SBHP. 13:45 13:53 ON BOTTOM, TIE-IN, PARK PRESSURE TOOL AT 5721' MD (MID PERFS). START RECORDING 20 MINUTE STATIC PRESSURE. SBHP = 1596 PSI. ii Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#114/D2 Survey Section Name SPERRY SUN BHI Rep. j~ilr~~ WELL DATA Target TVD (F-r) Target Coord, N/S Slot Coord, N/S -46,00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~ SS[~ Target Description Target Coord, LAN Slot Coord, LAN -597,00 Magn, Declination 27,410 Calculation Method MINIMUM CURVATURE Target Direction ................... _(_D.D_)_ ........ Build\Walk\DL per: 100ff~ 30m~ 10m~ Vert, Sec, Azim, .__ _306,95 Magn, to Map Corr, . ..... 27,_4__10__._ Map North to: 0T__H_E_.R ....................... i · II I Il I I I I I ' SURVEY DATA T ........ -~- ............ r- ............................. -T ........................... ~T ............................................................. Survey ,, I I "cie "o ~ Total Coordinate Build Rate / Walk Rate .... / ~urvey Inc. I M L, urse Vertical ............................ ~ ......... ua[e ~OOl Depth Angle Direction Length TVD ! Section N(+) / S(-) E(+) / W(-) DE ~,,u'ld (,+,1 Hlgn,!!,+; Comment ................... i__y.__p_e. ...... (_FT) ......... ! _D_D_) .......... _(D_D! ...... !F_'I~ ...... !F_T)_ ......................... (FO .............. (~_F-~_ ........ !~_e_r_.l_0~0 F~ ..... _~r_~p_[7_) ......... ~_e_T[ (,-; ................................... MWD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 23-AUG-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 6 3/4"M1X-AKQ-1.4 DEG. 23-AUG-98 MWD 202.95 0.28 229.15 81.95 202.95 0.04 -0.13 -0.15 0.34 0.34 23-AUG-98 MWD 384.27 : 0.41 226.47 161.32 384.27 0.24 -0.87 -0.96 0.07 0.07 23-AUG-98 MWD 554.41 0.62 208.48 170.14 554.40 0.21 -2.10 -1.84 0.15 0.12 23-AUG-98 MWD 645.41 0.68 249.03 91.00 645.39 0.42 -2.72 -2.58 0.50 0.07 23-AUG-98 MWD 740.77 1.80 295.49 95.36 740.73 2.19 -2.28 -4.46 1.49 1.17 23-AUG-98 MWD 831.71 4.22 313.95 90.94 831.54 6.91 0.66 -8.16 2.83 2.66 23-AUG-98 MWD 923.01 10.27 333.46 91.30 922.08 17.54 10.28 -14.22 7.06 6.63 21.37 23-AUG-98 MWD 1014.71 18.22 338.94 91.70 1010.89 37.05 31.01 -23.04 8.78 8.67 5.98 23-AUG-98 MWD 1105.81 20.80 336.17 91.10 1096.76 63.25 59.10 -34.69 3.01 2.83 -3.04 --. 23-AUG-98 MWD 1196.92 22.93 333.05 91.11 1181.31 93.31 89.72 -49.27 2.66 2.34 -3.42 23-AUG-98 MWD 1287.47 25.62 327.41 90.55 1263.86 127.50 121.95 -67.82 3.92 _ 2.97 -6.23 23-AUG-98 MWD 1378.62 27.59 323.57 91.15 1345.36 166.20 155.54 -90,97 2.87 2.16 -4,21 23-AUG-98 MWD 1468.59 31.46 318.65 89.97 1423.64 209.18 189.95 -118.87 5.07 4.30 -5.47 ~.~, ............................................................................................................................. ~-~ ............................... 23-AUG-98 MWD 1558.93 36.75 315.36 90.34 1498.43 259.04 226.90 -153.46 6.20 5.86 -3.64 . 23-AUG-98 MWD 1649.44 42.28 312.74 90.51 1568.23 316.16 266.87 -194.88 6.38 6.11 -2.89 '~J:? ..................... ?: 23-AUG-98 MWD 1745.85 45.94 311.18 96.41 1637,44 383.00 311.70 -244.79 3.96 3.80 -1.62 ~"' ~:; ::,~ ,,.r:,.,,.-,. 23-AUG-98 MWD 1841.34 50.81 309,83 95.49 1700,85 454.22 358.02 -299.07 5.21 5.10 -1.41 ~ ~i!'" 23-AUG-98 MWD 1936.92 56.68 306,53 95.58 1757,36 531.22 405.57 -359.66 6.74 6.14 -3.45 r~r,.,-,. .... 23-AU G-98 MWD 2030.90 63.32 304.10 93.98 1804.33 612.52 452.54 -426.06 7.41 7.07 -2.59 ==; 23-AUG-98 MWD 2124.81 67.81 304.20 93.91 1843.17 697.90 500.52 -496.80 4,78 4.78 0.11 i',:?~, 23-AU G-98 MWD 2311.16 65.97 305.13 186.35 1916.31 869.15 598.00 -637.77 1.09 -0.99 0.50 24-AUG-98 MWD 2595.93 68.25 306.93 284.77 2027.08 1131.43 752.32 -849.89 0.99 0.80 0.63 iii ~ '~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99763 Sidetrack No. Page 2 of 3 Company ARCO ALASKA,~ I__N.C.- .................................. Rig Contractor & No. PARKER - 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#114/D2 Survey Section Name SPERRY SUN BHI Rep. ~lrr~/~ WELL DATA Target-I-VD .... (FT) Target Coord. N/S ................... Slot Coord. N/S -46.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS'~i Target Description Target Coord. E/VV Slot Coord. E/VV -597,00 Magn. Declination 27.410 Calculation Method MINIMUM CURVATURE Target Direction ................. (Dp_)_ ......... Build\Walk\DL per: 100ft[~ 30m[~ 10m~_-i Vert. Sec. Azim. __~306_._9~5 ........ Magn. to Map Corr. __ _2_~7._41_._0_ .... Map North to: OT~H_ER ......................... SURVEY DATA .................. TSurvey Ii .............................................................................................................. ~ ....... { ~n,,~ : u,,~,, r, ........... Total Coordinate Build Rate 1 Walk Rate 24-AUG-98~ MWD I 2880.65 66.34 306.22 284.72 2136.97 1394.06 908.83 -1060.80 0.71 -0.67 -0.25 6 3/4"M1X-AKO-1.4 DEG. 24-AUG-98 MWD 3167.15 65.85 305.77 286.50 2253.07 1655.95 1062.77 -1272.71 0.22 -0.17 -0.16 24-AUG-98 MWD 3450.52 67.60 307.49 283.37 2365.04 ' 1916.23 1218.08 -1481.58 0.83 0.62 0.61 24-AUG-98 MWD 3733.06 67.36 306,56 282.54 2473,26 2177,22 1375.25 -1689.95 0,32 -0.08 -0,33 24-AUG-98 MWD 4017.69 66,20 306,29 284.63 2585.47 2438,78 1530,56 -1900.41 0,42 -0.41 -0,09 24-AUG-98 MWD 4207,12 64.58 304.93 189.43 2664,36 2610.95 1630.84 -2040,41 1,08 -0.86 -0.72 24-AUG-98 MWD 4396.70 59.69 302.97 93.96 2752.86 2778,29 ] 7 2_4:_3__4. ._ __ ......... _-_2_1_79.49' _2.76 -_2.64 -0._9._3_ 24-AUG-98 MWD 4491.27 56.61 301,92 94.57 2802.76 2858.36 1767,44 -2247.27 3.39 -3.26 -1.'11 24-AUG-98 MWD 4586.21 53.66 301.87 94.94 2857.03 2935.95 1808,59 -2313.40 3.11 -3.11 -0.05 24-AUG-98 MWD 4678.34 51.41 301.11 92,13 2913,06 3008.74 1846.79 -2375.74 2.53 -2.44 -0.82 24-AU G-98 MWD 4776.54 48.15 300,67 98.20 2976.47 3083.29 1885.29 -2440,08 3.34 -3.32 -0.45 24-AUG-98 MWD 4872.23 44,91 301.33 95.69 3042,29 3152,35 1921,04 -2499,60 3.42 -3.39 0.69 24-AUG-98 MWD 4966,85 41,78 302.02 94.62 3111,09 3217.02 1955.13 -2554,87 3.35 -3.31 0.73 24-AUG-98 MWD 5061.59 38,79 301,95 94,74 3183,36 3278.04 1987,58 -2606.82 3.16 -3.16 -0.07 25-AUG-98 MWD 5156.21 35.76 302.39 94.62 3258,64 · 3335,14 2018,08 -2655.33 3.21 -3.20 0.47 25-AUG-98 MWD 5250.87 33,69 304,20 94.66 3336,44 3388.94 2047,65 -2700,41 2.44 -2.19 1.91 25-AU G-98 MWD 5343.40 30.59 305.16 92.53 3414,78 3438,12 2075,64 -2740,89 3.40 -3.35 1.04 25-AU G-98 MWD 5437.77 27,32 305.85 94.37 3497,34 3483.78 2102,16 -2778.08 3.48 -3.47 0.73 25-AUG-98 MWD 5533.19 25.43 306.27 95.42 3582.83 3526.16 2127.11 -2812.35 1.99 -1.98 0.44 25-AU G-98 MWD 5723.17 24.67 307.42 189.98 3754.94 3606.60 2175,33 -2876.73 0.48 -0.40 0.61 25-AUG-98 MWD 5912.99 24,19 307.02 189.82 3927.76 3685.10 2222,82 , -2939,24 0.27 -0.25 -0.21 25-AUG-98 MWD 6102.21 23.30 305.45 189.22 4100.96 3761,28 2267,87 , -3000.68 0.58 -0,47 -0.83 25-AUG-98 MWD 6212,91 , 23.29 304.67 110.70 4202.64 3805.04 2293,02 ' -3036.52 0.28 -0,01 -0.70 SURVEY CALCULATIONAND FIELDWORKSHEETJob No. 0450-99763 Sidetrack No, Page 3 of 3 1 Company _A.__R_.C_O~A__L/~__SKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1D/1D#114/D2 Survey Section Name SPERRY SUN BHI Rep. ,, WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -46.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSi~ Target Description Target Coord. E/W Slot Coord. E/W -597.00 Magn. Declination 27.410 Calculation Method MINIMUM CURVATURE Target Direction .................... (.D_D_) ........ Build\Walk\DL per: lOOff~ 30m~ lOm~ Vert. Sec. Azim. __ _306.95 Magn. to Map Corr. ____27_._4_10__0 .... Map North to: QT_.H..E__R SURVEY DATA ........... ;-S-~v~/---~ .... ~ ..... i-""~--~ "e Oou~'~-e- ............................... -~(~,a~-~C~'r-8~-~at-e- ............... '['-B-~i~8-R~at~--'T-w-a-ik-R~t-~- F bury y ~n . mo Vertical .......................................... Date 5ool Depth Angle Direction Length TVD Section N(+)/S(-) E(+)/W(-) DL ~ B,,u~ld (,+,) Rgb,! !,-I-) Comment .................. ly_pe ........ _(_F~ ..... ! _j_u?) ........ !DB> ............. (_FT~ ........ (_~ ........................... I ...... ~_FT)_ ............... (FO ....... (Per ?__F_-O______u?_p__!?_ ....... _L_e~__.~-_~ ................................... 25-AUG-98 MWD 6270.00 23.29 304.67 57.09 4255.08 3827.59 2305.86 -3055.08 0.00 0.00 0.00 CLO.DIST= 3827.59'AZ1= 307.04 , --. -- .... -- ORI$tNA Kuparuk Unit Kuparuk 1D 1D.114 SURVEY REPORT 17 September, 1998 Your Ref: API-500292290800 Last Survey Date 25-August-98 Job# AKMMS0341 KBE- 112.10' DRILLING SERVICES Survey Ref: svy66 Sperry-Sun Drillin Se ices Survey Report for 1D-1'14 Your Ref: API-500292290800 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -112.10 0.00 121.00 0.000 0.000 8.90 121.00 202.95 0.280 229.150 90.85 202.95 384.27 0.410 226.470 272.17 384.27 554.41 0.620 208.480 442.30 554.40 645.41 0.680 249.030 533.29 645.39 740.77 1.800 295.490 628.63 740.73 831.71 4.220 313.950 719.44 831.54 923.01 10.270 333.460 809.98 922.08 1014.71 18.220 338.940 898.80 1010.90 1105.81 20.800 336.170 964.66 1096.76 1196.92 22.930 333.050 1069.21 1181.31 1287.47 25.620 327.410 1151.76 1263.86 1378.62 27.590 323.570 1233.26 1345.36 1468.59 31.460 318.650 1311.54 1423.64 1558.93 36.750 315.360 1386.33 1498.43 1649.44 42.280 312,740 1456.13 1568.23 1745.85 45.940 311,180 1525.34 1637.44 1841.34 50.810 309,830 1588.75 1700.85 1936.92 56.680 306,530 1645.26 1757,36 2030.90 63.320 304.10;' 1692.23 1804.33 2124.81 67,810 304.20L' 1731.07 1843.17 2311,16 65.970 305.130 1804.21 1916.31 2595.93 68.250 306.930 1914.98 2027.08 2880.65 66.340 306.220 2024.87 2136.97 3167.15 65.850 305.770 2140.97 2253,07 3450.52 67.600 307.490 2252.94 2365.04 3733.06 67.360 306.560 2361.16 2473.26 4017.69 66.200 306.290 2473.37 2585.47 4207.12 64.580 304.930 2552.26 2664.36 Local Coordinates Northings (ft) 0.00 N 0.00 N 0.13S 0.87 S 2.10S 2.72 S 2.28 S 0.68 N 10.28 N 31.01 N 59.10 N 89.72 N 121.95 N 155.54 N 189.95 N 226.90 N 268.87 N 311.70 N 358.02 N 405.57 N 452.54 N 500.52 N 598,00 N 752.32 N 908.83 N 1062.77 N 1218.09 N 1375.25 N 1530.56 N 1630.84 N Global Coordinates Eastings Northings Eastings (ft) (ft) (ft) 0.00 E 5959619.07 N 560490.62 E 0.00 E 5959619.07 N 560490.62 E 0.15 W 5959618.94 N 560490.47 E 0.96 W 5959618.19 N 560489.67 E 1.84 W 5959616.96 N 560488.80 E. 2.58 W 5959616.33 N 560488.07 E 4.46 W 5959616.75 N 560486.18 E 8.16 W 5959619.66 N 560482.46 E 14.22 W 5959629.24 N 560476.32 E 23.04 W 5959649.89 N 560467.34 E 34.69 W 5959677.89 N 560455.45 E 49.27 W 5959708.39 N 560440.63 E 67.82 W 5959740.47 N 560421.82 E 90.97 W 5959773.87 N 560398.40 E 118.87 W 5959808.05 N 560370.23 E 153.46 W 5959844.73 N 560335.34 E 194.88 W 5959884.36 N 560293.60 E 244.79 W 5959928.79 N 560243.33 E 299.07 W 5959974.67 N 560188.68 E 359.66 W 5960021.73 N 560127.70 E 426.06 W 5960068.16 N 560060.93 E 496.80 W 5960115.58 N 559989.81 E 637.77 W 5960211.91 N 559648.06 E 649.89 W 5960364.52 N 559634.71 E 1060.80 W 5960519.33 N 559422.54 E 1272.71'W 5960671.56 N 559209.39 E 1481.56 W 5960825.19 N 558999.28 E 1689.94 W 5960980.67 N 558789.66 E 1900.41 W 5961134.28 N 558577.95 E 2040.41 W 5981233.44 N 558437.15 E Dogleg Vertical Rate Section (°/~OOft) (ft) 0.00 0.000 . 0.00 0.342 0.04 0,072 0.24 0.154 0.21 0.499 0.42 1.489 2.19 2.833 6.91 7.061 17.54 8.784 37.05 3.008 63.25 2.562 93.31 3.919 127.50 2.868 166.20 5.073 209.18 6.200 259.04 6.380 316.16 3.960 383.00 5.208 454.22 6.742 531.22 7.411 612.52 4.782 697.90 1.089 869.15 0.990 1131.43 0.709 1394.06 0.223 1655.95 0.832 1916.23 0.316 2177.22 0.417 2438.78 1.076 2610.95 Comment Kuparuk 1D Continued... 17 September, 1998 - 14:19 - 2. DrfllQuest Sperry-Sun Drilling S ,et:vices Survey Report for 1D-114 Your Ref: API-500292290800 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth fit) fit) (ft) Local Coordinates Global Coordinates Northings Eastings Northings' Eastings (ft) fit) fit) (ft) 4302.74 62.170 303.840 2595.11 2707.21 1679.12 N 2110.94 W 5961281.14 N 558366.23 E 4396.70 59.690 302.970 2640.76 2752.86 1724.34 N 2179.49 W 5961325.81 N 558297.32 E 4491.27 56.610 301.920 2690.66 2802.76 1767.44 N 2247.27 W 5961368.36 N 558229.20 E 4586.21 53.660 301.870 2744.93 2857.03 1808.59 N 2313.39 W 5961408.98 N 558162.74 E 4678.34 51.410 301.110 2800.96 2913.06 1846.79 N 2375.74 W 5961446.68 N 558100.09 E 4776.64 48.150 300.670 2864.37 2976.47 1885.29 N 2440.08 W 5961484.66 N 558035.45 E 4872.23 44.910 301.330 2930.19 3042.29 1921.04 N 2499.60 W 5961519.93 N 557975.64 E 4966.85 41.780 302.020 2998.99 3111.09 1955.13 N 2554.87 W 5961553.57 N 557920.09 E 5061.59 38.790 301.950 3071.26 3183.36 1987.58 N 2606.82 W 5961585.60 N 557867.88 E 5156.21 35.760 302.390 3146.54 3258.64 2018.08 N 2655.33 W 5961615.71 N 557819.13 E 5250.87 33.690 304.200 3224.34 3336.44 2047.66 N 2700.40 W 5961644.92 N 557773.82 E 5343.40 30.590 305.160 3302.68 3414.78 2075.65 N 2740.89 W 5961672.58 N 557733.11 E 5437.77 27.320 305.850 3385.24 3497.34 2102.16 N 2778.08 W 5961698.80 N 557695.70 E 5533.19 25.430 306.270 3470.72 3582,82 2127.11 N 2812.35 W 5961723.47 N 557661.24 E 5723.17 24.670 307.020 3642.83 3754,93 2175.11 N 2876.90 W 5961770,95 N 557596.31 E 5912.99 24.190 307.020 3815.66 3927.76 2222.38 N 2939.58 W 5961817,71 N 557533.25 E 6102.21 23.300 305.450 3988.86 4100.96 2267.43 N 3001.02 W 5961862,27 N 557471.45 E 6212.91 23.290 304.670 4090.54 4202.64 2292.58 N 3036.85 W 5961887.12 N 557435.41 E 6270.00 23.290 304.670 4142.97 4255.07 2305.42 N 3055.41 W 5961899.82 N 557416.75 E All data is in feet unless otherw,'~e stated. Directions and coordinates are relative to True North. ,,, Vertical depths are relative to V~ ell. Northings and Eastings are relative to Well. The Dogleg Sevedty is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 306.950° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6270.00ft., The Bottom Hole Displacement is 3827.60ft., in the Direction of 307.036° (True). Dogleg Vertical Rate Section (°/100ft) (ft) 2.719 · 2696.33 2.761 - 2778.29 3.391 2858.36 3.108 2935.95 2.528 3008.74 3.337 3083.29 3.423 3152.35 3.346 3217.02 3.156 3278.04 3.215 3335.14 2.443 3388.94 3.395 3438.12 3.483 3483,78 1.990 3526,16 0.434 3606.60 0.253 3685.11 0.577 3761.29 0.279 3805.04 0.000 3827.59 Comment Projected Survey Kuparuk 1D Continued... 17 September, 1998 - 14:19 - 3 - DrlllQue$! Sperry-Sun Drilling Services Survey Report for fD.l'14 Your Ref: API-500292290800 Kuparuk Unit Comments Measured Depth (ft) 0.00 6270.00 Station Coordinates TVD Northings Easfings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4255.07 2305.42 N 3055.41 W Comment Tie-on Survey Projected Survey Kuparuk 1D 17 September, 1998 - 14:19 - 4. DrillQuest WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-114, AK-MM-80341 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~3, Anchorage, AK 99518 11)-114: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22908-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22908-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ,.,- 19c)8 5631 Silverado Way, Suite G · Anchorage, Alaska 99518. (907) 273-3500 · Fax (907) 273-3535 ~ nrn~r InH~fri,',Q Inn ri I:! I I_1_1 ~ G S I:a I=1 L/I l-- I~ S WELL LOG TRANSM1TrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-114, AK-MM-80341 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22908-00 . 5631 Silverado Way, Suite G .Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 sper, 0 I=! I I._1_ I I~] ES S E F:I~./I C E S 22-Sep-98 A©GCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-114 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 6,270.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276~7542 August 17, 1998 To~n McKav Kupantk Drilling Teaxn Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 1D-114 ARCO Alaska, Inc. Permit No. 98-159 Sur. Loc 46'FNL. 597'FEL. SEC 23. T1 IN. Ri0, UM Btmhole Loc. 2263'FSL. 1613'FEL. SEC 23, TllN. R10E. UM Dear Mr. McKay: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as pan of the Permit to Drill application for Kupamk River Unit Well No. 1D-114. Please note that any disposal of fluids generated from fids drilling operation which are pumped down the surface/production casing annulus of a permitted existing well on Drill Site ID must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in volume greater tlum 35.000 barrels through the annular space of a single well or for a period longer than one )'ear. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Conunission petroleum field inspector on the North Slope pager at 659-3607. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Gan]e, Habitat Section w, o encl. Department of Environmental ConserYation w;o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Reddll E lb TypeofWell Exploratory F' StratigraphicTest E Development Oil r, Re-Entry F' Deepen E Service X Development Gas [-- Single Zone X Multiple Zone r~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 46' FNL, 597' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ),. ~/_. 8. Well number Number 2134' FSL, 1785' FEL, Sec./I,4', T11N, R10E, UM 1D-114 #U-630610 At total depth 9. Approximate spud date Amount 2263' FSL, 1613' FEL, Sec. 23, T11 N, R10E, UM 8/18/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-115 6208' MD 2263' @ TD feet 12.8' @ 340' feet 2560 4234' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 64.45° Maximum surface 1381 psig At total depth (TVD) 1815 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' +_200 CF 8.5" 5.5" x 15.5# L-80 BTC M 5391' 41' 41' 5432' 3529' 563 Sx Arcticset III & 8.5" 3.5" 9.3# L-80 8rd Mod 776' 5432' 3529' 6208' 4234' 453 Sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented Measured del:~. ~. ~ ~,~= ~ V~~, Conductor Surface Intermediate . .~ .~ ~ -. Production 0 ~i I f-~ i i'~ 1 ~J~'/~. L /~,U.,~i 0G '~998 Liner '~' ,~-~ '~'~ ~ /~ "~ Perforation depth: measured 'Naska 0il & Gas Cons. O0mmissi0,n t~,e vertica~ Anchorage 20. Attachments Filing fee X Property plat E BOP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Timevs depth plot [~ Refraction analysis E~ Seabed report [~ 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ' - ' '7" ,~tck4Y Title Kuparuk Drilling Team Leader Date ~ i'll ~'~ ./ - ' Commission Use Only Permi~;~mb~, IAPInumber IApprovaldato .~ (~ See cover letter for - ~'¢" ~ 50- O 2_~ -- ~- ~ ~'(2 ~2' { other requirements Conditions of approval Samples required ~ Yes ~' No Mud l6grequired F; Yes ~' No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~;; Yes E~ No Required working pressure for BOPE F' 2M ~, aM [~ 5M [--" 10M E~ 15M Other: ORIGINAL SIGNED BY Robert N. Chdstenson by order of ~,~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 ' Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 4, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-114 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designated as a monobore injection well using a 5 ~" x 3 Y2" tapered casing string, with 3- 1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-114, such as shallow gas. There have been ten (10) Kuparuk wells and (19) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy. of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is August 18, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Scott Goldberg Operations Drilling Engineer CC: West Sak 1D-114 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill, Case and Completion Plan for West Sak 1 D-114 (D2) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . . . Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 5 Y2" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is close to the surface, a top job may be performed in lieu of utilizing the port collar. ~ Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Before stinging into seal bore, freeze protect well with enough diesel to cover Permafrost. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig. 10. 11. If necessary, rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 12. Rig up E-line unit and RIH with through-tubing perforating guns. 1D-114 (D2) Page I SG, 08/04/98, v.1 13. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 14. Install back pressure valve, shut in and secure well. 1D-114 (D2) Page 2 SG, 08/04/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-114 (D2) Drilling Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-114 (D2) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-114 (D2) Page I SG,08/04/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,524' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3945 ft)(0.46 - 0.11 psi/fi) = 1381 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 5-1/2" 15.5# LB0 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-114 (D2) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-114 (D2) is WS 1D-115. As designed, the minimum distance between the two wells would be 12.8' at 340' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will b_...._.._~e p.u_mped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-114 (D2) surface casing /production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 1D-114 (D2) Page 2 SG,08/04/98,v.1 West Sak 1 D-114 (D2) Injector Completion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' TAM International 5-1/2" Port Collar Stnd. Grade BTC Threads set +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 5432' MD / 3529' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/~ 5432' MD / 3529' TVD) to (+/- 6208' MD / 4234' TVD) G. 3-1/2" Vetco-Gray iubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Iiaker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands SG, 8/4/98, v.1 1 609 !200 800 ~ 2;00 2400 I-- 2700 I 3000 3300 3600 3900 4200 O,of¢~ ,, .~,ch ['or: BROCK-WAY O°:e ¢~otted : II-Jun-98 p~o: ~eference ;s ~ 10-114/D2 C~cr~r~te~ crc ;~ f~et ,~ference slo~ ~IIA T~e Vert:CQI Depths cra reference RK8 (Pcrker TD LOCATION: 2263' FSL, 1613' FEL SEC. 23, Ti!N, R10E RKB ELEVATION: 112' aska, In ............ mStructure : Pad 10 Well: 114 [Field : Kuparuk River Unit Location : North Slope, AlaskaJ <- West (feet) 3300 3000 2700 2400 21 O0 1800 1500 1200 900 600 300 I I I I I ! I I I I I I I I I I I I I I I TD Base West Sok Sands - West Sak A3 Wesi Sak Sands / EOD Top Ugnu Sands TARGET LOCATION: 2134' FSL, 1785' FEL SEC. 14, TIlN, RIOE TARGET TV0=3762 TMD=5690 DEP=3626 NORTH 2180 WEST 2898 Begin Angle Drop 306.95 AZIMUTH , 3626' (TO TARGET) I KOP TVD=700 TMD=?00 DEP=0 15.oo EOC 1~?0000. O0 Base Permafrost ~ B/ PERMAFROST ~D=1647 TMD=IB15 DE, =501 , ~0 ECG ~D=1734 TMD=1989 OEP=652 SUR~%~%~TiON: ~ I 46' FNL, 597' FEL ~ SEg. 23, Ti :~, RiGE MAXI~~ ANGLE ~ ' ..... 64.45 DEG %4~00 BLS: 3.00 de9 per i00 ft 59.00 30.00 ~ARGgT - A3 TVD=3?~2 TMB=5690 ~~P=3626~ ~~ A NT~_I ~ B/ W SAK SNDS ~D=4052 TMD=6008 BEP=3759~, TARGET ANGLE TD CSG PT ~D-42~4 TRfD-6208 DEP-2842~k 24.5 DEG ..... 30O i = 2400 ~ 21CC F 1800 ~ ! 200 4500 300 900 800 300 C i I I I i i I I i I '1 i i I i i i i i i i i I i i I i 300 600 900 1200 1500 1800 21 O0 2400 2700 ,3000 3300 3600 5900 Vertical Secfion (feel) -> Azimuth 306.95 with reference 0.00 N, 0.00 E from slot #114 g 0 c~.,~ ~ ~;.¢ For: HROCKWAY ITr~e Ven,tel ~eOtns ore telerate iRCO A!aska; ,, Inc. ........... ~4 --- [ [FieI~tlU~tuZukP:~velrOunit Location:North Slope, AIaskoI <- West (feet) 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 ~ ~), '~ .i ~ooi ',,, '\ ',~ ',, ,, \ :~oo ~ 1 ',,, \ ~ 300 '~, ~oo ", ", '~ 2ooo: / ~ l- ~co _~ ~ ", % ", ", ", ~, 1300 / ~ ',,~ ',, ',, '~ 700 \ ~oo ~ao _1 OX'",, ~ood',., ",, ",, ",, ",, -~ ° ! % '",. "',,, \ ", ',",, ,boo ;" / ' i ",. ",, ", \ ", ", ", ;' l ,/8oo,L~ I- ~o/ ~ooo',,, ",, "" \ "" '", '", oo ,'" / ,," ,'/-¢7 / 1 .,., ,,,., ',,,,, ',,,,:oo ,,,'~ ~oo ',. ~oo ~ ,,- ~ ,.,' ,,,' i-~° ' "-,, ",,, "',,. \ ",, ",, ",, ~oo.,.,'" ~oo~ ,,,, ,,,' I- -~ ',, .,, ',, \ ',, ',, ',, ..- 7oo .~,' ;"~oo/~ I '.,,,,,. \ ,,,,,oo ,, " " "'- ", \ '% i ",, "., ~o~,,. \ ',, ',, --,,. ~oo.,,, " ". ', 1100 " " -. ... ,~, , u k ~ot .,,, ,,,, ',,,,,. ,,,,,,,, ,, J ~. ".. "... ",, \ ",. ',, Z.--.-" i/ //~'°~ I k~ '.,,, ,,,, ',,, \ ,,, \ 700 " ,-" ~ aO/-/' / ~oo-t ~'"... ,....,., ',,,,. \ ',,, ,, ~oo...-~oo/'i~oo ,.-~oo ". ", ',, ", ", ", ......... ' :~oo _~ -... ,..... ",,, \,ooo;~oo ,, ~oo~~ | ~ '... 900 '.. ',. .. x ', ', ~ , ~o~,-~. '-... '... '... ,,oo ~oS,,., ~ ',,, ',,~'~'o,o~,/i ~"'-. "-. ",. -'.: .... ". k '", ', ~oo ~oo~/,~o~ , ,,,. ,.. ~o i ",.. "-.. ',,, ",,. ",, % ",,6o~, -~oo / .... I '"'-. '"". ""'. '"", '"- \ '", "',,-oo 4oo I i- 1.-.. "'-..~oo '-,.,?oo ",,.,. '-.,.,. ,od'-,, ",,,aoo',,, ,,~ ,c '--"-. "",.. ~'k'~,.,ooo '"'.,. 'k ".~oo ® 1~ -,,, ,,, ",,.'-,,. ',, ",.,oo'.. t , 1 "---.. ~oo "'--. '.... .... ---...,oo - ~o 4 "%- "-.. '"-. ".. ....... ~oo I ~ "-. "-. "- ' ............ 600 ~ ~,,~, I -J~ZL 1800 ~ "". 1200'"'30'0'- : -~' , I ~ 1700 --'-. --'.. ".. : .~ I ~ ,70o ~6oo'~._~oo ~5ob.. -... -. 6oo I L ou o0 t L 500 - / 20 i ' !zoo," i / ' ' ............ ~ '-.. 500 / i- o ................ 8oo / A I , ~ ~ , ~ ~ ~ ~ ' ~ ' ~ ' ' ~ ' 8~ ~ 6~0 ~ 4'0 ~ 2~0 ' ~ * 2~0 ~ z'O ~ ~ 240 220 200 180 160 140 120 100 0 0 . 60 <- Wesf (feet) 1200~ .......... ~700 -~ .,,'/'""~~ k 20 ......... ,5._o0 5OO 11 O0 40 l Z 0 c,~..¢~ ~,~,¢, For: EROCKTIAY O~ate Clotted. ~ ~-Jun-98 Pct Reference ;3 '~fi 10-114/D2 Ver~. ~5. C~rd;nates ~r~ ;n ~eet reference slot ~114. True V~,cel aska, In S,r-~--uc,u~e--7' Pod ,--~ ...... ;,e-,, :, 44 Field : Kuparuk River Unit LocaHon : North Slope, A I <- West (feet) 800 760 720 680 640 600 550 520 480 440 400 560 .320 280 240 200 ! 60 "'"', "'"',, '""', -~ooo ", L 64c 4 ~.. '".,",, '",. \ '~,, ' ] ",. ", ", 15oo "'"'",, ~ " " % ". ". ~ ~-00 600 -~ % ', ' J-,"'"'-, """,, '"',, ~ / ' '"'". ' '"'-.. '"'. '"". "".~ 1500 ~"k' ~° 1 ""- "", "'-, "', '"',. \ ", / '". '"-. , ", '". ", ~ ", L ~ "-,, '-. '~oo '"' "' "" ! ". "- 1200 ', ". ", " 520 -~ ", "- ", ', "", j "-,...., "-,..,.. ',,,,, ',,,,, "'-..... "--.... '.....'..... '.,.. \ ~1 ,~oo-.,, "-.. ',,,,.",,,.',,,, \ '"" "%' 44c i ',,,, ',,.. ',,,. '~ fi ',. - ",. ",, ",. ~6C ] '"-. "-. "'. ", ", n.~- ~60 J ' ~c~ - . --...,... 1 !000 2oo .... ~ 1500 k,?-'y~ ? 2oo ........----. 1 50~,' .. ,.'"".... 1601 120 8O 4O 800 ........ j 2700 2600 2500 ~' ' 2¢0d 3100 ~ i i i I i i i i I i i i I 760 720 680 640 600 560 520 <- 250~ t 480 Wesf · ! 60 2O i000 ...... 1300 ....... 2100 2200-~- .~'~ 2000 1900 ~ 80 1800 I I i i I i i i i t i i i I 440 400 360 320 280 240 200 160 (f~t) A I Z 0 ~ .............. ~,o .... zo= ..... ~. I /Field: Kuparuk River Unit Location : Nodh Slope, Alaska[ -"- (D i100 <- West (feet) 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 ] ! I I I I I I I I [ [ ! I I I I I 1 I t I I I I I I f I ",, ",, x 1 gOO '",. ",, ',. 2300 k. 4000 ", 2000". \,, ",, '"~, 3900 ". !800 '"', '", '",, ',. 3800 '", 1806 ',,,, ',,,,2200 ,,,, -k~ 3700 ",, "',. '", \', 2200 ',~ 3600 ",, "., "',, ",, ~. ~5oo ",, i7oo C~ 19oo',.. ',, ,,, x, 3400 ',, "-.~.. ",. ',,, ',, ~ -~ "~ 1700~ '-,.., ',,., ',,21 O0 "% 21 O0 X 3wOO '", , oo% -.....?,oo ",,,, '-,,, ",,,, · 5Co ~ "'-,.~ '"',.. "',,,"',,, \',~ 2000 26oo'-.... "-..?000 ,,,, ,,.2000 \,,, \ 3000 1400 '". "', ". ", "\X,,, ",. "-, ", ',, ',, '-,~, ',.. 1700'"-,, ',, "~ 1900 '~ 2500 '-.,. "-.. 1900 ',, ", ", ~^_ '-. '. '. '.. .... "'".. "~ z~uu 1,300 ] ".... "-.... ',.., '~.\.1 900 ",,.. t '-, '-. ~ ~uu 1600~',. ",. x X~ "-.... ",,,.. ' '.,.,, ",,,. IT~ ""'-.. '""-. \", '"k 18oo lO00 g00 8OO 7OO 600 500 400 3~Z--~,-~_200 ......... ~ 1700 ----._4~ oo -- ,300 ~ ........ i ,3o0 3700 .............. ]600 200 '~3500 3400 -- ~ ........... ~, O0 ' 200 100 [ r [ [ [ [ i i [ i i [ [ t i ] I i t i i i i [ i i i I ~ 100 2100 2000 1900 1800 1700 1600 1500 1400 1~00 1200 1100 1000 900 800 700 600 · . <- West (feel) .~u --...,. "-, "-,~ 1 700 ", " 3000 '--... '--. '-. ., ', ", r 2900 ~ "-. "-. 1500% ",, "' 2800 "--. "-. ".. ". \, ", . ~ 10oo -- 2~°°~"~ ~2~- '"- ,,, ,,, ,,,~ooq '. '- '-. ', 2600~ '"',, '"'.~ 1600 '"' %' ~".~i 2500 ~ '"'. "'-. ",, ",, "~ k 900 240~ ",~ "-. 1 400", ", L ~ 2100 '-... '-.... '", "\ 2300 ~ '",.... ",. -.1500- ",,,,",, ,[- 800 -,,... z,uu ~ '"' '" t 7cc '-. '-.. ! 400 I ~ ' ooo % "' i- 600 ..... ... 2100 '~ '"' '"' ....... '"--, '"% t300 F '---.. '-. '- F 5'30 ........ Z??..o' ........ ~ ....... _ /x Z 0 ARCO Alaska,e Creo',~ W ~;~c. For: BROCKWAY [ P Well : I 14 D~tc Olotted: l t-Jun-98I ~ ~iOt ~,n~, :, WS !0-11'/0~ V~,,. ~. J I [ Location : North Slope, Alaskaj Vel,cai Oeol~ ore reference RK8 (Parker 2800 2700 2600 250O 2400 2JO0 ~ 220O 2100 2000 1900 i8°° 170C 160C <- West (feet) 3400 3300 3200 3100 .3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 2900 '.,. 2800 -, -. ',~ 2700 200 '.. " 4;0o"-., '"', 4000,%.` ",~ 2600 39oo'",.. '"",,.,, 3800'%.. .. 3700'%,. '-.. 3600'%.. "-. '., 2500 350¢,., "... 340~=-.. ".... 3300 '.. '.. 320~"-. '-,,.2400 3 00'.. '-. 3000`%`. '"'-%2300 290~-.. -.. 280~"'.. '-.,,. 2200 " b 2500"~ '"'x, '., 2700 ',, '~ 2700 '. '.. 2600 2400"~ '",, ",, 2500 · " 22CC ~- 2200 ~ 21C0 1500 i40C i 300 1200 1100 k 2ceo I h Z P 1900 0 L -- ¢ -+- ? ~700 h · 270¢,.. -~ 21 O0 F 1600 ~150c 260~'-. "' l h 13CC ~ ~200 3400 i ~00 100o 3400 5500 5200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 i900 1800 · <- West (feet) ARCO Alaska, INC".] Well: 114 Structure : Pad 1D Field : Kuparuk River Unit Location : North Slope, A askoj WELL PROFILE DATA o.~ o.~ o.~ 30695 o.oo o.~ o.~ o.~ o.~ 700.C0 0.~ 3C6.g5700.00 O.CO 0.00 C.~ . 19aS.g*6~.45~06.95 17~3.8~~¢1.74 -520.73651.63 5.~ 0.~ 42~.gl 6%.45306.95 2687.96 1591.%5 -2115.45 2647.23 0.~ 5~J2,472~.~ Jc6.g5 3619.00 21 ~.98 -2~5.g 1 3561.32 3.~ ~C8.51 2'.~ a05.95 ~52.00225g.fil -~.~ 3758.65 0.~ 62C8,312~.~ 3C6.g5 4233.gg 230g.47 -~g.87 %1~oo ,530 ,, , q~. 32'~,, ,. ,, 51"0-~ ~oo 340 35O 10 2O 3OO 3O 1300 ] c~,o,,~ =, ~;.=, For: BROCKWAY ~or~note~ ore ;n f~t r~/er~ce slct ~1!4. Ver[[ccl DeDths ~re rcfer~e R~ {Pc~er ~245].~; 50 i 290 >70 280 270 260 qso ,ao 2to! 80 100' 250 !10 240 250 · ~"-'"' 210 200 190 1500 130'e ,,,' /700 180 170 160 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Weli ARCO Alaska, Inc. Pad 1D 114 slot #114 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : WS 1D-114/D2 Vets. #5 Our ref : prop2212 License : Date printed : 11-Jun-98 Date created : 17-Apr-97 Last revised : 8-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n70 18 0.863,w149 30 36.313 Slot Grid coordinates are N 5959618.683, E 560490.334 Slot local coordinates are 46.00 S 597.00 W : Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D i N A T E S 0.00 0.00 306.95 0.00 0.00 N 0.00 500.00 0.00 306.95 500.00 0.00 N 0.00 700.00 0.00 306.95 700.00 0.00 N 0.00 800.00 5.00 306.95 799.87 2.62 N 3.48 900.00 10.00 306.95 898.99 10.47 N 13.91 1000.00 15.00 306.95 996.58 23.47 N 31.20 W 1100.00 20.00 306.95 1091.93 41.55 N 55.22 W 1200.00 25.00 306.95 1184.28 64.54 N 85.80 W 1300.00 30.00 306.95 1272.96 92.29 N 122.68 W 1400.00 35.00 306.95 1357.27 124.59 N 165.61 W 150Q.00 40.00 306.95 1436.58 161.17 N 214.24 W 1600.00 45.00 306.95 1510.28 201.77 N 268.21 W 1700.00 50.00 306.95 1577.82 246.08 N 327.11 W 1800.00 55.00 306.95 1638.68 293.76 N 390.48 W 1814.64 55.73 306.95 1647.00 301.00 N 400.11 W 1900.00 60.00 306.95 1692.39 344.45 N 457.86 W 1988.94 64.45 306.95 1733.83 391.74 N 520.73 W 2000.00 64.45 306.95 1738.60 397.74 N 528.70 W 2500.00 64.45 306.95 1954.27 668.93 N 889.18 W 3000.00 64.45 306.95 2169.95 940.11 N 1249.65 W 3500.00 64.45 306.95 2385.62 1211.30 N 1610.13 W 4000.00 64.45 306.95 2601.30 1482.49 N 1970.61 W 4200.91 64.45 306.95 2687.96 1591.45 N 2115.45 W 4249.13 63.00 306.95 2709.31 1617.45 N 2150.01 W 4349.13 60.00 306.95 2757.02 1670.28 N 2220.22 W 4449.13 57.00 306.95 2809.26 1721.53 N 2288.35 W 4549.13 54.00 306.95 2865.90 1771.07 N 2354.20 W 4649.13 51.00 306.95 2926.77 1818.76 N 2417.59 W 4749.13 48.00 306.95 2991.70 1864.46 N 2478.35 W 4782.14 47.01 306.95 3014.00 1879.09 N 2497.80 W 4849.13 45.00 306.95 3060.53 1908.07 N 2536.31 W 4949.13 42.00 306.95 3133.06 1949.44 N 2591.31 W 5049.13 39.00 306.95 3209.09 1988.48 N 2643.21 W 5149.13 36.00 306.95 3288.42 2025.08 N 2691.85 W 5249.13 33.00 306.95 3370.82 2059.12 N 2737.10 W PROPOSAL LISTING Page 1 Your ref : WS 1D-114/D2 Vets. #5 Last revised : 8-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 KOP 5.00 4.36 5.00 17.41 5.00 39.05 5.00 69.11 5.00 107.36 5.00 153.52 5.00 207.24 5.00 268.09 5.00 335.63 5.00 409.34 5.00 488.65 5.00 500.69 Base Permafrost 5.00 572.96 5.00 651.63 EOC 0.00 661.61 0.00 1112.70 0.00 1563.79 0.00 2014.89 0.00 2465.98 0.00 2647.23 Begin Angle Drop 3.00 2690.48 3.00 2778.35 3.00 2863.60 3.00 2946.01 3.00 3025.33 3.00 3101.36 3.00 3125.70 Top Ugnu Sands 3.00 3173.89 3.00 3242.72 3.00 330?.66 3.00 3368.53 3.00 3425.16 5349.13 30.00 306.95 3456.08 2090.53 N 2778.85 W 3.00 5449.13 27.00 306.95 3543.95 2119.21 N 2816.98 W 3.00 5532.47 24.50 306.95 3619.00 2140.98 N 2845.91 W 3.00 5689.61 24.50 306.95 3761.99 2180.15 N 2897.98 W 0.00 5689.62 24.50 306.95 3762.00 2180.15 N 2897.99 W 0.00 3477.40 3525.12 3561.32 Top ~e~t Sak Sands / EOD 3626.48 TARGET - West Sak 43 3626.49 WS 1D-D2 Rvsd 26-JUan-98 6000.00 24.50 306.95 4044.44 2257.53 N 3000.84 W 0.00 3755.20 6008.31 24.50 306.95 4052.00 2259.61 N 3003.60 W 0.00 3758.65 Base West Sak Sands 6208.31 24.50 306.95 4233.99 2309.47 N 3069.87 W 0.00 3841.58 TD All data is in feet unless otherwise stated. Coordinates from slot #114 and TXrD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3841.58 on azimuth 306.95 degrees from wellhead. Total Dogleg for wellpath is 104.39 degrees. Vertical section is from wellhead on azimuth 306.95 degrees. Calculation uses the minimum cuz-vature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-114/D2 Vets. #5 Last revised : 8-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 700 1814 1988 4200 4782 5532 56S9 5689 6008 6208 00 64 94 91 14 47 62 31 31 7O0 1647 1733 2687 3014 3619 00 3761 99 3762 00 4052 00 4233.99 00 00 83 96 00 0.00 N 0.00 E KOP 301.00 N 400.11 W Base Permafrost 391.74 N 520.73 W EOC 1591.45 N 2115.45 W Begin Angle Drop 1879.09 N 2497.80 W Top Uguu Sands 2140.98 N 2845.91 W Top West Sak Sands / EOD 2180.15 N 2897.98 W TARGET - West Sak A3 2180.15 N 2897.99 W WS 1D-D2 Rvsd 26-JUan-98 2259.61 N 3003.60 W Base West Sak Sands 2309.47 N 3069.87 W TD Casing positions in string 'A' ...... =========7=== =========== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6208.31 4233.99 2309.47N 3069.87W 5 1/2" Casing Targets associated with this wellpath ====================== ============7 Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-D2 Rvsd 26-JUa 557575.000,5961775.000,-2.000 3762.00 2180.15N 2897.99W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-114/D2 Vers. ~5 Last revised ~ 8-Jun-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 306.95 0.00 46.00 S 597.00 W 0.00 0.00 500.00 0.00 306.95 500.00 46.00 S 597.00 W 0.00 0.00 700.00 0.00 306.95 700.00 46.00 S 597.00 W 0.00 0.00 800.00 5.00 306.95 799.87 43.38 S 600.48 W 5.00 4.36 900.00 10.00 306.95 898.99 35.53 S 610.91 W 5.00 17.41 1000.00 15.00 306.95 996.58 22.53 S 628.20 W 5.00 39.05 1100.00 20.00 306.95 1091.93 4.45 S 652.22 W 5.00 69.11 1200.00 25.00 306.95 1184.28 18.54 N 682.80 W 5.00 107.36 1300.00 30.00 306.95 1272.96 46.29 N 719.68 W 5.00 153.52 1400.00 35.00 306.95 1357.27 78.59 N 762.61 W 5.00 207.24 1500.00 40.00 306.95 1436.58 115.17 N 811.24 W 5.00 268.09 160~.00 45.00 306.95 1510.28 155.77 N 865.21 W 5.00 335.63 1700.00 50.00 306.95 1577.82 200.08 N 924.11 W 5.00 409.34 1800.00 55.00 306.95 1638.68 247.76 N 987.48 W 5.00 488.65 1814.64 55.73 306.95 1647.00 255.00 N 997.11 W 5.00 500.69 1900.00 60.00 306.95 1692.39 298.45 N 1054.86 W 5.00 572.96 1988.94 64.45 306.95 1733.83 345.74 N 1117.73 W 5.00 651.63 2000.00 64.45 306.95 1738.60 351.74 N 1125.70 W 0.00 661.61 2500.00 64.45 306.95 1954.27 622.93 N 1486.18 W 0.00 1112.70 3000.00 64.45 306.95 2169.95 894.11 N 1846.65 W 0.00 1563.79 3500.00 64.45 306.95 2385.62 1165.30 N 2207.13 W 0.00 2014.89 4000.00 64.45 306.95 2601.30 1436.49 N 2567.61 W 0.00 2465.98 4200.91 64.45 306.95 2687.96 1545.45 N 2712.45 W 0.00 2647.23 4249.13 63.00 306.95 2709.31 1571.45 N 2747.01 W 3.00 2690.48 4349.13 60.00 306.95 2757.02 1624.28 N 2817.22 W 3.00 2778.35 4449.13 57.00 306.95 2809.26 1675.53 N 2885.35 W 3.00 2863.60 4549.13 54.00 306.95 2865.90 1725.07 N 2951.20 W 3.00 2946.01 4649.13 51.00 306.95 2926.77 1772.76 N 3014.59 W 3.00 3025.33 4749.13 48.00 306.95 2991.70 1818.46 N 3075.35 W 3.00 3101.36 4782.14 47.01 306.95 3014.00 1833.09 N 3094.80 W 3.00 3125.70 4849.13 45.00 306.95 3060.53 1862.07 N 3133.31 W 3.00 3173.89 4949.13 42.00 306.95 3133.06 1903.44 N 3188.31 W 3.00 3242.72 5049.13 39.00 306.95 3209.09 1942.48 N 3240.21 W 3.00 3307.66 5149.13 36.00 306.95 3288.42 1979.08 N 3288.85 W 3.00 3368.53 5249.13 33.00 306.95 3370.82 2013.12 N 3334.10 W 3.00 3425.16 5349.13 30.00 306.95 3456.08 2044.53 N 3375.85 W 3.00 3477.40 5449.13 27.00 306.95 3543.95 2073.21 N 3413.98 W 3.00 3525.12 5532.47 24.50 306.95 3619.00 2094.98 N 3442.91 W 3.00 3561.32 5689.61 24.50 306.95 3761.99 2134.15 N 3494.98 W 0.00 3626.48 5689.62 24.50 306.95 3762.00 2134.15 N 3494.99 W 0.00 3626.49 KOP Base Permafrost EOC Begin Angle Drop Top Ugnu Sands Top ~est Sak Sands / EOD TARGET~- West Sak A3 WS 1D~D2 Rvsd 26-juan-98 6000.00 24.50 306.95 4044.44 2211.53 N 3597.84 W 0.00 3755.20 6008.31 24.50 306.95 4052.00 2213.61 N 3600.60 W 0.00 3758.65 Base West Sak Sands 6208.31 24.50 306.95 4233.99 2263.47 N 3666.87 W 0.00 3841.58 TD All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3841.58 on azimuth 306.95 degrees from wellhead. Total Dogleg for wellpath is 104.39 degrees. Vertical section is from wellhead on azimuth 306.95 degrees. Calculation uses the minimum cuz-vature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : wS 1D-114/D2 Vets. Last revised : 8-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 700.00 1814.64 1988.94 4200.91 4782.14 5532.47 5689.61 5689.62 6008.31 6208.31 700 00 1647 00 1733 83 2687 96 3014 00 3619 00 3761 99 3762.00 4052.00 4233.99 46.00 S 255.00 N 345.74 N 1545.45 N 1833.09 N 2094.98 N 2134.15 N 2134.15 N 2213.61 N 2263.47 N 597.00 W KOP 997.11 W Base Permafrost 1117.73 W EOC 2712.45 W Begin Angle Drop 3094.80 W Top Ugnu Sands 3442.91 W Top West Sak Sands / EOD 3494.98 W TARGET - West Sak A3 3494.99 W WS 1D-D2 Rvsd 26-JUan-98 3600.60 W Base West Sak Sands 3666.87 W TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 46.00S 597.00W 6208.31 4233.99 2263.47N 3666.87W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-D2 Rvsd 26-J~3a 557575.000,5961775.000,-2.000 3762.00 2134.15N 3494.99W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : WE 1D-114/D2 Vets. #5 Last revised : 8-Jun-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 306.95 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 500.00 0.00 306,95 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 700.00 0.00 306.95 700.00 0.00 N 0.00 E 0.00 1.83 1.83 1.05 N/A 800.00 5.00 306.95 799.87 2.62 N 3.48 W 4.36 2.11 2.09 1.20 306.95 900.00 10.00 306.95 898.99 10.47 N 13.91 W 17.41 2.53 2.37 1.35 306.95 1000.00 15.00 306.95 996.58 23.47 N 31.20 W 39.05 3.26 2.66 1.51 306.95 1100.00 20.00 306.95 1091.93 41.55 N 55.22 W 69.11 4.44 3.00 1.69 306.95 1200.00 25.00 306.95 1184.28 64.54 N 85.80 W 107.36 6.14 3.37 1.89 306.95 1300.00 30.00 306.95 1272.96 92.29 N 122.68 W 153.52 8.42 3.79 2.13 306.95 1400.00 35.00 306.95 1357.27 124.59 N 165.61 W 207.24 11.30 4.25 2.44 306.95 1500.00 40.00 306.95 1436.58 161.17 N 214.24 W 268.09 14.81 4.74 2.82 306.95 1600.00 45.00 306.95 1510.28 201.77 N 268.21 W 335.63 18.95 5.25 3.30 306.95 1700.00 50.00 306.95 1577.82 246.08 N 327.11 W 409.34 23.71 5.76 3.87 306.95 1800.00 55.00 306.95 1638.68 293.76 N 390.48 W 488.65 29.08 6.26 4.53 306.95 1814.64 55.73 306.95 1647.00 301.00 N 400.11 W 500.69 29.95 6.33 4.64 306.95 1900.00 60.00 306.95 1692.39 344.45 N 457.86 W 572.96 35.02 6.74 5.29 306.95 1988.94 64.45 306.95 1733.83 391.74 N 520.73 W 651.63 40.71 7.14 6.04 306.95 2000.00 64.45 306.95 1738.60 397.74 N 528.70 W 661.61 41.42 7.19 6.13 306.95 2500.00 64.45 306.95 1954.27 668.93 N 889.18 W 1112.70 73.66 9.40 10.46 306.95 3000.00 64.45 306.95 2169.95 940.11 N 1249.65 W 1563.79 106.05 11.62 14.85 306.95 3500.00 64.45 306.95 2385.62 1211.30 N 1610.13 W 2014.89 138.48 13.84 19.26 306.95 4000.00 64.45 306.95 2601.30 1482.49 N 1970.61 W 2465.98 170.93 16.06 23.68 306.95 4200.91 64.45 306.95 2687.96 1591.45 N 2115.45 W 2647.23 183.97 16.95 25.46 306.95 4249.13 63.00 306.95 2709.31 1617.45 N 2150.01 W 2690.48 187.04 17.17 25.88 306.95 4349.13 60.00 306.95 2757.02 1670.28 N 2220.22 W 2778.35 193.08 17.65 26.70 306.95 4449.13 57.00 306.95 2809.26 1721.53 N 2288.35 W 2863.60 198.80 18.16 27.47 306.95 4549.13 54.00 306.95 2865.90 1771.07 N 2354.20 W 2946.01 204.17 18.69 28.19 306.95 4649.13 51.00 306.95 2926.77 1818.76 N 2417.59 W 3025.33 209.18 19.23 28.87 306.95 4749.13 48.00 306.95 2991.70 1864.46 N 2478.35 W 3101.36 213.83 19.78 29.49 306.95 4782.14 47.01 306.95 3014.00 1879.09 N 2497.80 W 3125.70 215.24 19.96 29.67 306.95 4849.13 45.00 306.95 3060.53 1908.07 N 2536.31 W 3173.89 218.09 20.33 30.05 306.95 4949.13 42.00 306.95 3133.06 1949.44 N 2591.31 W 3242.72 221.98 20.89 30.57 306.95 5049.13 39.00 306.95 3209.09 1988.48 N 2643.21 W 3307.66 225.49 21.44 31.03 306.95 5149.13 36.00 306.95 3288.42 2025.08 N 2691.85 W 3368.53 228.62 21.98 31.44 306.95 5249.13 33.00 306.95 3370.82 2059.12 N 2737.10 W 3425.16 231.39 22.51 31.80 306.95 5349.13 30.00 306.95 3456.08 2090.53 N 2778.85 W 3477.40 233.80 23.02 32.12 306.95 5449.13 27.00 306.95 3543.95 2119.21 N 2816.98 W 3525.12 235.87 23.51 32.39 306.95 5532.47 24.50 306.95 3619.00 2140.98 N 2845.91 W 3561.32 237.36 23.90 32.58 306.95 5689.61 24.50 306.95 3761.99 2180.15 N 2897.98 W 3626.48 240.18 24.63' 32.96 306.95 5689.62 24.50 306.95 3762.00 2180.15 N 2897.99 W 3626.49 240.18 24.63 32.96 306.95 6000.00 24.50 306.95 4044.44 2257.53 N 3000.84 W 3755.20 245.77 26.09 33.69 306.95 6008.31 24.50 306.95 4052.00 2259.61 N 3003.60 W 3758.65 245.92 26.12 33.71 306.95 6208.31 24.50 306.95 4233.99 2309.47 N 3069.87 W 3841.58 249.53 27.06 34.19 306.95 Ail data is in feet unless otherwise stated. Coordinates from slot #114 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3841.58 on azimuth 306.95 degrees from wellhead. Vertical section is from wellhead on azimuth 306.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-114/D2 Vets. #5 Last revised : 8-Jun-98 POSITION UNCERTAINTY SUMMARY ============================== Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6208 ARCO (H.A. Mag) User specified 249.53 27.06 34.19 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trakmanual. Comments in wellpath ===== MD TVD Rectangular Coords. Comment 700.00 700.00 1814.64 1647.00 1988.94 1733.83 4200.91 2687.96 4782.14 3014.00 5532.47 3619.00 5689.61 3761.99 5689.62 3762.00 6008.31 4052.00 6208.31 4233.99 0 00 N 301 00 N 391 74 N 1591 45 N 1879 09 N 2140 98 N 2180.15 N 2180.15 N 2259.61 N 2309.47 N 0.00 E KOP 400.11 W Base Permafrost 520.73 W EOC 2115.45 W Begin Angle Drop 2497.80 W Top Ugnu Sands 2845.91 W Top West Sak Sands / EOD 2897.98 W TARGET - West Sak A3 2897.99 W WS 1D-D2 Rvsd 26-JUan-98 3003.60 W Base West Sak Sands 3069.87 W TD Casing positions in string 'A' =========================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6208.31 4233.99 2309.47N 3069.87W 5 1/2" Casing Targets associated with this wellpath .... ================================= Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-D2 Rvsd 26-JUa 557575.000,5961775.000,-2.000 3762.00 2180.15N 2897.99W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 306.95 0.00 0.00N 0.00E 500.00 0.00 306.95 500.00 0.00N 0.00E 700.00 0.00 306.95 700.00 0.00N 0.00E 800.00 5.00 306.95 799.87 2.62N 3.48W 900.00 10.00 306.95 898.99 10.47N 13.91W 1000.00 15.00 306.95 996.58 23.47N 31.20W 1100.00 20.00 306.95 1091.93 41.55N 55.22W 1200.00 25.00 306.95 1184.28 64.54N 85.80W 1300.00 30.00 306.95 1272.96 92.29N 122.68W 1400.00 35.00 306.95 1357.27 124.59N 165.61W 1500.00 40.00 306.95 1436.58 161.17N 214.24W 1606.00 45.00 306.95 1510.28 201.77N 268.21W 1700.00 50.00 306.95 1577.82 246.08N 327.11W 1800.00 55.00 306.95 1638.68 293.76N 390.48W 1814.64 55.73 306.95 1647.00 301.00N 400.11W PROPOSAL LISTING Page 1 Your ref : WS 1D-114/D2 Vets. #5 Last revised : 8-Jun-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 0.00 0.00 560490.33 5959618.68 0.00 0.00 560490.33 5959618.68 0.00 0.00 560490.33 5959618.68 5.00 4.36 560486.83 5959621.28 5.00 17.41 560476.34 5959629.03 5.00 39.05 560458.94 5959641.90 5.00 69.11 560434.78 5959659.77 5.00 107.36 560404.02 5959682.52 5.00 153.52 560366.92 5959709.97 5.00 207.24 560323.74 5959741.91 5.00 268.09 560274.81 5959778.09 5.00 335.63 560220.52 5959818.25 5.00 409.34 560161.27 5959862.07 5.00 488.65 560097.51 5959909.23 5.00 500.69 560087.83 5959916.40 1900.00 60.00 306.95 1692.39 344.45N 457.86W 5.00 572.96 560029.73 5959959.37 1988.94 64.45 306.95 1733.83 391.74N 520.73W 5.00 651.63 559966.49 5960006.14 2000.00 64.45 306.95 1738.60 397.74N 528.70W 0.00 661.61 559958.47 5960012.08 2500.00 64.45 306.95 1954.27 668.93N 889.18W 0.00 1112.70 559595.83 5960280.30 3000.00 64.45 306.95 2169.95 940.11N 1249.65W 0.00 1563.79 559233.20 5960548.52 3500.00 64.45 306.95 2385.62 1211.30N 1610.13W 0.00 2014.89 558870.57 5960816.74 4000.00 64.45 306.95 2601.30 1482.49N 1970.61W 0.00 2465.98 558507.93 5961084.96 4200.91 64.45 306.95 2687.96 1591.45N 2115.45W 0.00 2647.23 558362.22 5961192.73 4249.13 63.00 306.95 2709.31 1617.45N 2150.01W 3.00 2690.48 558327.46 5961218.45 4349.13 60.00 306.95 2757.02 1670.28N 2220.22W 3.00 2778.35 558256.82 5961270.70 4449.13 57.00 306.95 2809.26 1721.53N 2288.35W 3.00 2863.60 558188.28 5961321.39 4549.13 54.00 306.95 2865.90 1771.07N 2354.20W 3.00 2946.01 558122.04 5961370.39 4649.13 51.00 306.95 2926.77 1818.76N 2417.59W 3.00 3025.33 558058.27 5961417.55 4749.13 48.00 306.95 2991.70 1864.46N 2478.35W 3.00 3101.36 557997.15 5961462.76 4782.14 47.01 306.95 3014.00 1879.09N 2497.80W 3.00 3125.70 557977.58 5961477.23 4849.13 45.00 306.95 3060.53 1908.07N 2536.31W 3.00 3173.89 557938.84 5961505.89 4949.13 42.00 306.95 3133.06 1949.44N 2591.31W 3.00 3242.72 557883.51 5961546.81 5049.13 39.00 306.95 3209.09 1988.48N 2643.21W 3.00 3307.66 557831.31 5961585.42 5149.13 36.00 306.95 3288.42 2025.08N 2691.85W 3.00 3368.53 557782.37 5961621.62 5249.13 33.00 306.95 3370.82 2059.12N 2737.10W 3.00 3425.16 557736.84 5961655.29 5349.13 30.00 306.95 3456.08 2090.§3N 2778.85W 3.00 3477.40 557694.85 5961686.36 5449.13 27.00 306.95 3543.95 2119.21N 2816.98W 3.00 3525.12 557656.49 5961714.73 5532.47 24.50 306.95 3619.00 2140.98N 2845.91W 3.00 3561.32 557617.39 5961736.25 5689.61 24.50 306.95 3761.99 2180.15N 2897.98W 0.00 3626.48 557575'~00 5961775.00 5689.62 24.50 306.95 3762.00 2180.15N 2897.99W 0.00 3626.49 557575.00 5961775.00 6000.00 24.50 306.95 4044.44 2257.53N 3000.84W 0.00 3755.20 557471.53 5961851.53 6008.31 24.50 306.95 4052.00 2259.61N 3003.60W 0.00 3758.65 557468.76 5961853.58 6208.31 24.50 306.95 4233.99 2309.47N 3069.87W 0.00 3841.58 557402.08 5961902.90 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #114 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3841.58 on azimuth 306.95 degrees from wellhead. Total Dogleg for wellpath is 104.39 degrees. Vertical section is from wellhead on azimuth 306.95 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,114 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-114/D2 Vers. #5 Last revised : 8-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 700.00 700.00 0.00N 1814.64 1647.00 301.00N 1988.94 1733.83 391.74N 4200.91 2687.96 1591.45N 4782.14 3014.00 1879.09N 5532.47 3619.00 2140.98N 5689.61 3761.99 2180.15N 5689.62 3762.00 2180.15N 6008.31 4052.00 2259.61N 6208.31 4233.99 2309.47N 0.00E 400 520 2115 2497 2845 2897 2897 3003 3069 KOP 11W Base Permafrost 73W EOC 45W Begin Angle Drop 80W Top Ugnu Sands 91W Top West Sak Sands / EOD 98W TARGET - West Sak A3 99W WS 1D-D2 Rvsd 26-JTJan-98 60W Base West Sak Sands 87W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot T%-D Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6208.31 4233.99 2309.47N 3069.87W 5 1/2" Casing Targets associated with this wellpath :================= --- Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-D2 Rvsd 26-JUa 557575.000,5961775.000,-2.000 3762.00 2180.15N 2897.99W 9-Oct-96 A~CO Alaska, Inc. Pad 1D 114 slot #114 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref : WS 1D-114/D2 Vets. #5 Our ref : prop2212 License : Date printed : 11-Jun-98 Date created : 17-Apr-97 Last revised : 8-JLu~-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n70 18 0.863,w149 30 36.313 Slot Grid coordinates are N 5959618.683, E 560490.334 Slot local coordinates are 46.00 S 597.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARA~CES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-5142'>, WS 1D-113/C1 Vets WS 1D~125/H2 Vers WS 1D~123/G1 Vets WS 1D-134/L5 Vets WS 1D~132/K4 Vets WS 1D-131/L3 Vets WS 1D~128/K2 Vets PMSS <0 - 7340'> PMSS <0-5462 >, PMSS <0-4414 >, PMSS <0-4530 >, PMSS <0-4515 >, PMSS <0-4590 >, PMSS <0-5205 >, PMSS <0-4850 >, PMSS <0-5126 >, PMSS <381-6092'> PMSS <1957-5265'> PMSS <0-5015'>, ,ll5,Pad 1D #4,,113,Pad 1D #5,,125,Pad 1D #4,,123,Pad 1D #3,,134,Pad 1D #3,,132,Pad 1D #3,,131,Pad 1D #3,,128,Pad 1D ,,lO,Pad 1D ,129,Pad 1D ,121,Pad 1D ,120,Pad 1D ,119,Pad 1D ,1lB,Pad 1D ,117,Pad 1D ,109,Pad 1D ,106,Pad 1D ,,105,Pad 1D ,,133,Pad 1D ,135,Pad 1D PMSS <0-4778'>,,130,Pad 1D PMSS <0-5047'>,,124,Pad 1D WS 1D-116/E1 Vets. #4,,116,Pad 1D WS 1D-112/A1 Vets. #4,,112,Pad 1D WS 1D-iii/B2 Vets. #5,,Ill,Pad 1D Closest approach with 3-D Last revised Distance M.D. Diverging from M.D. 2-Jun-98 12.8 340.0 : 2600.0 2-Jun-98 15.0 280.0 6208.3 5-Ju~-98 240.0 500.0 500.0 9-JLu~-98 165.0 280.0 280.0 27-May-98 465.0 300.0 300.0 27-May-98 390.0 240.0 240.0 27-May-98 375.0 240.0 240.0 1-Jun-98 285.0 600.0 600.0 28-Apr-98 510.0 120.0 120.0 2-J~n-98 344.3 300.0 300.0 2-Jun-98 130.1 725.0 725.0 2-Jun-98 117.7 725.0 725.0 2-Jun-98 98.6 750.0 750.0 2-Jun-98 60.0 100.0 700.0 2-Jun-98 37.6 540.0 540.0 2-Jun-98 105.0 100.0 100.0 2-Jun-98 135.7 1050.0 1050.0 2-Jun-98 179.5 300.0 300.0 2-Jun-98 402.1 340.0 340.0 2-Jun-98 479.3 680.0 680.0 2-Jun-98 359.9 420.0 420.0 2-Jun-98 217.2 725.0 725.0 2-Jun-98 28.7 540.0 540.0 2-Jun-98 30.0 240.0 240.0 8-Jun-98 75.0 540.0 540.0 Minimum Distance method WS 1D-110/C3 Vers WS 1D- 108 WS 1D- 101 WS 1D-104 WS 1D-103 WS 1D- 102 WS 1D- 107 WS 1D- 151 WS 1D-138 WS 1D-161 WS 1D-160 WS 1D-159 WS ID- 157 WS 1D-156 #4 11~ .ad iD /A3 Vers #4 /C5 Vets #3 /AT Vets #3 /B6 Vers #3 /A5 Vets #3 /B4 Vers #1 /Gll Vers. #1 108,Pad 1D 101,Pad 1D 104,Pad 1D 103,Pad 1D 102,Pad 1D 107,Pad 1D ,151,Pad 1D /K6 Vers. #1, 138,Pad 1D /L7 Vers. #1, 161,Pad 1D /KS Vets. #1, 160,Pad 1D /L9 Vets. #1, 159,Pad 1D /K10 Vets. #1 ,157,Pad 1D /J9 Vets. #1,,156,Pad 1D WS 1D-155/H8 Vers. #1,,155,Pad 1D WS 1D-154/J11 Vers. #1,,154,Pad 1D WS 1D-153/H10 Vets. #1,,153,Pad 1D WS 1D-150/F10 Vets. #1,,150,Pad 1D WS 1D-152/G9 Vers. #1,,152,Pad 1D WS 1D-149/F8 Vets. #1,,149,Pad 1D WS 1D-148/E11 Vers. #l,,148,Pad 1D WS 1D-147/E9 Vets. #1,,147,Pad 1D WS 1D-146/D10 Vets. #1,,146,Pad 1D WS 1D-145/Cll Vets. #1,,145,Pad 1D WS 1D-144/D8 Vets. #1,,144,Pad 1D WS 1D-143/C9 Vets. #1,,143,Pad 1D WS 1D-139/B8 Vets. #1,,139,Pad 1D WS 1D-140/A9 Vets. #1,,140,Pad 1D WS 1D-142/B10 Vets. #1,,142,Pad 1D WS 1D-141/All Vets. #1,,141,Pad 1D WS 1D-158/L11 Vets. #1,,158,Pad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D TOTCO Sur,;ey,,WS-8,Pad 1D 1D-B Version #3,,1D-B,Pad 1D 1D-F Version #2,,1D-F,Pad 1D 1D-D Version #2,,1D-D,Pad 1D PGMS <0-8365 >,,1,Pad 1D PGMS <0-9783 >,,2,Pad 1D PGMS <0-8070 >,,3,Pad 1D PGMS <0-7502 >,,4,Pad 1D PGMS <0-8930 >,,5,Pad 1D PGMS <0-8610 >,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D WS 1D-122/F2 Vets. #4,,122,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D 2-Jun-98 2-Jun-98 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-May-98 21-May-98 24-Nov-97 24-Nov-97 24-Nov-97 10-Dec-97 4-Aug-92 4-Aug-92 4-Aug-92 13-Nov-97 13-Nov-97 6-Novo97 29-Apr-98 27-May-98 9-Jun-98 27-May-98 90 120 238 193 208 223 133 452 527 593 579 565 536 522 508 494 480 438 466 425 411 398 384 371 354 338 275 290 326 315 550 497 557 332 419 302 229 162 33 77 196 317 437 80 255 149 270 0 0 0 0 0 0 .1 .6 .0 .7 .4 .1 .7 .5 .4 .4 .4 .8 .5 .1 .5 .0 .6 .0 .6 .7 .6 7 6 3 9 0 0 0 3 .0 9 9 6 1 0 0 0 2 0 2 0 280.u 280.0 280.0 280.0 280.0 300.0 300.0 300 0 360 0 300 0 300 0 260 0 300 0 300 0 400 0 300 0 300 0 300 0 400 0 500 0 300.0 500.0 480.0 500.0 725.0 725.0 700.0 750.0 660.0 580.0 260.0 600.0 40.0 600.0 725.0 700.0 1325.0 420.0 950.0 20.0 700.0 20.0 460.0 750.0 300.0 620.0 240.0 280.0 280.0 280.0 280 0 280 0 300 0 300 0 300 0 360 0 300 0 300 0 260 0 300 0 300 0 400 0 300 0 300 0 300 0 400 0 500 0 5621 5 500 0 480 0 500 0 725.0 725.0 700.0 750.0 660.0 580.0 260.0 600.0 40.0 600.0 725.0 700.0 1325 0 420 0 6200 0 2O 0 700 0 680 0 460 0 750 0 300 0 620 0 240 0 'Z0" DIVERTER SCHEi ¥;4TIC Kuparuk River Unit West Sak Operations 6 5 4 3 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20" - 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line Will Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 . .. --3-5/8" 5000 psi BOP 5;ack Kuparuk River Unit West Sak Operations - Injector Wells 6 5 4 3 2 1. 16' Starting Head 2. 7-1/16' 5000 psi Tubing Head 3. 7-1/16' x 13-5/8' 5000 psi Double Studded Adapter/Spacer Spool 4, 13-5/8' 5000 psi x 13-5/8' 5000 psi Spacer Spool 5. 13-5/8' 5000 psi Pipe Rams 6. 13-5/8' 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8' 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8, 13-5/8' 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi low and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.2 FRr. I~ : KUPIJRRK TOOL HOUSE HO,: 659 81 D.S. 1-D 108~ 110~ 112 113 114 116 t18 9 11g 120 121 122 125 127 l~g I32 ~ 7 '1 07-27-98 !1 \'""~15 ' rills SURVEY SCALE: 1~ = I ~iLE P .02 LEGEND 0 £XISTINC CONDUCTOR5 'AS-BUlL T' CONDUCTON LOCA Il'ION ARCO Alaska, Inc. ~ K6~0416 07,/22/98 S;'E SHEgT ~ 2 ~'OR NOTES AND LOCATION iNFORMATION _,, ,i ! ii · C/J}L ~ AssoCZ,r~s, ~C. A~EA ' ID ~OOULE XX ONIT- BEILL m~ ~ST SAK PHASE lB - ~LL CONDUCTORS AS-BUILT ....... t CEA-D10X-610~15 .. ~EET, 1~2 _ I _. FROM: KUPURAK TOOL. HOUSE tAX NO.: 659 768! 0?-2?-98 1J:l$ R£VI 3ATE I 8Y J CK .J'^~P ~ NO~5 CONDUCTORS ARE L~A~O ~fN PROTRACTED SECTIONS ) ~ ,~ ~-~ . c~oucro~s ¢-&. ~-o¢ox-¢w~o,o r~ c~oucro~s CEA-DIDX-610~IJ FOR CONDUCTORS Sec. 14, T. 11 N., R. IOE. , . - __ ,,~ .... No. [ Y X Lat. Long. F.~.'L,IF, CL, Pad O.C, . ~,, -. . ~08 5,~59.738. BZ 560,490.5~ 70' rS' 02.045' f49' 30' 3~.2~X" ' 74' 5~' ~.~' 62.4' 1~0 5,959,708.86 560,4~0.58 70* 18' 01.750" t4~* 30' ~6.2E~" 44' 596' 70. E' 64.5' ~1 5,959,69~.95 560,490.60 ~ 70' t8' ~f. 604" . ~4S' 30' ~6.287" .. 29' 59~' ...~0,~' ~4.5" Sec. 23, T. 11 N., R, 10 E. F.N.L,F.~.L. Pod O.G. , -- , I13 ) 5.95&6JJ, gJ ~$0,490.56 70' 18' O~,OIJ" t49' 30' J~.J02" J;' 59~ 70,~' ~J, 2'j 114 ] 5,955,519.07 5~0,4S0.62 . 70' I8' 0a867' t49' JO' 3E. JO4' 46' 5~7' 70.6' ~J. 2'[ ,,5 5. g59, Saa. g~ ,O,,gO. OJ 70',8'00.5,0' ,49' JO' i,.J,,' 76' 597' ~.,' ,t3', ~23 5,959,453.8~ 560,490.69 70' 17' 59.242' ~49' JO' 3~.J41' ~ 2tt' 598' ~0.6' 64.2' ., ,. , _~~~_ " ~ ~ .~-',.. . .. ~~YOR'S, CER~F!CA I HEREBY CE~TtFF rH~r 1 LICENSED TO ~RACTICE L~ND 5URVEYfNO IN THE ST4TE OF~_ ~ ..... ~' "' AS OF JULY 2~, I998. ..~ , LOUNSBURY & ASSOCIATES, INC. ii ii AREA' I0 ~ULE ' ~ UNIT: Ol ~ DREL ~ 1-D ARCO Alaska, Inc. ~ ~s~ S~K ~.~ ~e - ~ coNDuctors i '1 I LK810416 07/22/98 CEA-D1DX-610~16 i i II I 1D-114 Cement Volumes Surface Hole Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess ,feet inches Ibs/ft inches bbl/ft bbl/ft feet feet feet Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours % % % % % % Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg 'ft3/sx gal/sx hours % % bbls sacks 95.99348 452.9440254 bbls sacks · WELL PERMIT CHECKLIST COMPANY /'~ ,.~ FIELD & POOL ADMINISTRATION DATE INIT CLASS /- ~ WELL NAME ,/~"~P~.~ //~) '-//~Z74/. PROGRAM: exp [] dev [] redrll [] servywellbore seg I) ann. disposal para req I1 GEOL AREA ~ ~'(__.) UNIT# //2/~;;:~ ON/OFF SHORE c'~ ~t~ ANNULAR DISPOSAL 35. APPR DATE (A) will contain waste in a suitable rece~y,j~g zone; ....... (B) will not contaminate freshwate~ cause drilling waste... to surface; (C) will not impair mech~r~l integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool' and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: WM~'~ ~--~-~I:~I~i~DWJ , ~ JDH ' RNC co (.o s'//~' - M:che~,list rev 05/29/98 dlf: C :\msoffice\wordiar~\diarla\chcc,(:ldir. fl APPR DATE Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~ Oc~O .psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. N N N N 30. Permit can be issued w/o hydrogen sulfide measures ..... ~YY ,r~,,2r/~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............... Y N 33. Seabed condition survey (if off-shore) ............. 34. Cogtact,nam, e/phon,e.for weekly progress repods ....... Y N lexp~oramry omy] With proper cementing records, this plan Y N ,Annular disposal has not been rcqucstcd as part o£the Permit to Drill application for Kuparuk River Unit Well No. 1 D- ~_4L~_. Plcasc note that an,,' disposal of fluids gcncratcd from this drilling operation which arc pumped down thc surface/production casing m~nulus of a permitted existing xvell on Drill Site ID must comply xvith thc rcquircmcnts and limitations of 20 AAC 25.080. Approval of this pcrmit to drill docs not authorize disposal of drilling xvastc in a volun]o grca~r~ than 35.000 barrels through thc annular spacc ora single xvcll or for a period longer than o.,jFe~ year. GEOLOGY ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPE DATE 26. ~,,(~ _~lrl (~---~ 27. -28. 29. 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Inspection Type : COMMENTS: } q g - J ~-(l Memory Multi-Finger Caliper Log Results Summary CONOCOPHILLlPS (ALASKA) INC. July 29,2005 6511 1 3.5" 9.3 lb. EUE 8rd Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1D-114 Kuparuk Alaska 50-029-2290800 Surface 5,525 Ft. (MD) Corrosive & Mechanical Damage Inspection This caliper data is tied into the OS Nipple @ 5,430' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 59% @ 4,612'. Wall Penetrations ranging from 20% to 59% wall thickness are recorded in 142 of the 182 joints logged. The damage recorded appears mostly in the form of Line Corrosion and/or Lines of Pitting. There are no areas of significant Cross Sectional Wall loss recorded. Deposits restrict the ID to 3.73" @ 2,147'. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion Line Corrosion Line of Pitting Line Corrosion Line Corrosion ( 59%) ( 57%) ( 56%) ( 56%) ( 55%) Jt. Jt. Jt. Jt. Jt. 146 @ 103 @ 43 @ 165 @ 168 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits I Field Engineer: N. Kesseru Min ID = 2.73" Min ID = 2.74" Min ID = 2.75" Min ID = 2.76" Min ID = 2.76" "',. '.... "'.' 'i· -. ....,. i '.~:¡, -:' 'ìOO\:- ;jCi~N~\!EL ,14Uh '.} J I..." ,~,j Analyst: J. Thompson Jt. Jt. Jt. Jt. Jt. 68 70 67 69 62 @ @ @ @ @ 4,612 Ft. (MD) 3,258 Ft. (M D) 1,373 Ft. (MD) 5,206 Ft. (MD) 5,308 Ft. (MD) 2,147 Ft. (MD) 2,211 Ft. (MD) 2,146 Ft. (MD) 2,178 Ft. (MD) 1,957 Ft. (MD) Witness: C. Fritzpatrick ProActive Diagnostic Services, Ine. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 fax: (281) 565··1369 E-mail: PDS@memorylog.com Prudlloe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds. Well: Field: Company: Country: 10-114 KUPARUK CONOCOPHILLlPS ALASKA INC USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 EUE-8rd Penetration and Metal Loss (% wall) _ penetration body 200 11IM metal loss body .~ l--b o 0 to 1 to 1 0 to 20 to 40 to 1% 10% 20% 40% 85% 150 100 50 over 85% Number of joints analysed (total = 182) pene. 0 6 34 89 53 loss 24 158 0 0 0 o o Damage Configuration ( body) 150 100 50 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 167) 21 6 140 0 0 PDS Report Overview Body Region Analysis _ penetration body o °1 J:::- :liE- ~.: '~\\\\i H' 48~·i~..;~.. .... , M\ ,,\-',= r=- :îo.~(\:ì·~\~~ .' '~'\I'-;;\ ~ ~ '\ .. .)..~\.\\}. . ,: \ \...., . · 'Ii.., Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 29,2005 MFC 24 No 00387 1.69 24 J. Thompson Nom. Upset Upper len. 3.5 ins 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) ~ metal loss body 50 100 98 148 ~. '~"' j ,:' .~~\." ..f.'M....:. '. ..~...~·.....t..:..II,.. ,~ \ :....' . . " I.' '. ; ~\"'t-\.\; . 1,',. .'\'i\ \,,~ A ~.' ., \.:... ):-;.~' "\ ~. . ~ r~\ \~.~ .. ". .:\....\ J."! \..' \ .. , ; hh't~ : \i~~:\\i~' 1 ' ... :~~~, =. 'I' ,..... I .... ",~,~:~,= :,~=t ~., q ~ .:; \;,.... I ..,~ ~\'Î~.:~I"\\, :~: ·l· .: .,t. \ 1~'\);'~~"~"):'~ -:'~~ ~:'i""':¡ ~'''''\\\. . , GLM 1 Bottom of Survey = 172 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 10-114 Body Wall: 0.2 54 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 2.992 in Country: USA Survey Date: July 29, 2005 Joint Jt. Depth Pen. Pen. Pen. MC'tal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) (~) (Ins.) 0 50 100 .1 28 0 0.02 7 1 2.89 PUP 1 32 0 0.04 14 1 2.92 Shallow corrosion. Lt. Deposits. 1.1 63 () 0.03 13 () 2.92 PUP Shallow corrosion. 1.2 71 () 0.04 16 4 2.91 PUP Shallow pittinR. 2 79 0 0.03 13 2 2.91 Shallow pittinR. 3 110 0 0.03 11 4 2.92 4 141 0 0.04 15 1 2.92 Shallow corrosion. 5 173 0 0.03 12 :3 2.91 6 204 0 0.04 15 4 2.91 Shallow pittinR. Lt. Deposits. 7 236 0 0.04 14 2 2.92 Shallow corrosion. 8 266 0 0.03 11 1 2.89 9 298 0 0.02 9 1 2.90 10 328 0 0.03 11 2 2.91 11 357 0 0.03 10 1 2.91 12 388 0 0.03 11 1 2.91 13 419 0 0.03 11 1 2.90 14 451 0 0.03 12 'I 2.88 15 482 0 0.03 12 1 2.90 Shallow pittinR. 16 513 0 0.03 11 1 2.90 17 545 0 0.04 17 0 2.89 Shallow corrosion. 18 575 0 0.03 11 1 2.89 19 607 0 0.03 13 3 2.92 Shallow pitting. 20 638 0 0.03 13 2 2.92 Shallow corrosion. 21 668 0 0.04 14 3 2.92 Shallow pittinR. 22 700 0 0.03 13 1 2.90 Shallow pitting. 23 731 0 0.03 13 2 2.92 Shallow pittinR. 24 761 0 0.03 13 2 2.92 Shallow pitting. 25 790 0 0.02 9 1 2.92 26 822 0 0.02 9 2 2.91 27 853 0 0.04 15 2 2.92 Shallow pitting. 28 884 0 0.03 13 2 2.90 Shallow pitting. 29 915 0 0.04 15 1 2.91 Shallow pittinR. 30 947 0 0.02 8 1 2.92 Lt. Deposits. 31 978 0 0.03 13 1 2.90 Shallow pitting. 32 1009 0 0.05 20 1 2.89 Shallow pitting. Lt. Deposits. 33 1041 0 0.07 26 2 2.92 Isolated Pitting. Lt. Deposits. 34 1073 0 0.05 20 1 2.90 Isolated Pitting. 35 1104 0 0.04 17 1 2.91 Shallow pitting. Lt. Deposits. 36 1136 0 0.04 14 2 2.91 Shallow pittinR. 37 1167 0 0.04 16 1 2.92 Shallow pitting. Lt. Deposits. 38 1199 0 0.08 30 2 2.90 Isolated PittinR. 39 1231 0 0.08 31 2 2.91 Isolated Pittng. Lt. Deposits. 40 1262 0 0.06 24 2 2.92 Line of Pits. Lt. Deposits. 41 1294 0 0.08 31 1 2.89 Line of Pits. Lt. Deposits. 42 1326 0 0.07 27 2 2.89 Line of Pits. Lt. Deposits. 43 1358 0 0.14 56 2 2.91 Line of Pits. Lt. Deposits. 44 1389 0 0.13 51 6 2.90 Line of Pits. Lt. Deposits. 45 1421 0 0.07 28 2 2.91 Line of Pits. Lt. Deposits. 46 1452 0 0.08 33 2 2.92 Line of Pits. Lt. Deposits. 47 1484 0 0.12 47 6 2.90 Line Corrosion. Lt. Deposits. I Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 1 D-114 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 2.992 in Country: USA Survey Date: July 29,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) (10 (Ins.) 0 50 100 48 1515 0 0.10 38 :~ 2.91 Line Corrosion. Lt. Deposits. 49 1547 0 0.07 27 2 2.90 Line Corrosion. Lt. Deposits. 50 1579 0.06 0.12 47 ì 2.91 Line Corrosion. Lt. Deposits. 51 1607 0 0.10 40 :~ 2.91 Line Corrosion. 52 1639 0 0.10 39 4 2.89 Line Corrosion. Lt. Deposits. 53 1671 0 0.10 39 .1 2.91 Line Corrosion. 54 1702 0 0.11 43 5 2.89 Line Corrosion. Lt. Deposits. 55 1734 0 0.09 36 3 2.89 Line Corrosion. Lt. Deposits. 56 1766 0 0.08 33 2 2.87 Line Corrosion. Lt. Deposits. 57 1797 0 0.12 48 6 2.86 Line Corrosion. Lt. Deposits. 58 1829 0 0.10 39 4 2.84 Line Corrosion. Lt. Deposits. 59 1861 0 0.10 38 4 2.82 Line Corrosion. Lt. Deposits. 60 1893 0 0.08 33 3 2.86 Line Corrosion. Lt. Deposits. 61 1924 0 0.11 42 .... 2.78 Line Corrosion. Lt. Deposits. .) 62 1956 0 0.09 34 4 2.76 Line CorrQsion. Lt. Deposits. 63 1988 0 0.10 39 4 2.83 Line Corrosion. Lt. Deposits. 64 2020 0 0.10 41 4 2.81 Line Corrosion Lt. Deposits. 65 2051 0 0.12 49 6 2.79 Line Corrosion Lt. Deposits. 66 2083 0 0.12 47 7 2.81 Line Corrosion Lt. Deposits. 67 2114 () 0.10 39 ß 2.75 Line Corrosion 68 2146 0 0.09 37 9 2.73 Line Corrosion Lt. Deposits. 69 2178 0 0.09 37 6 2.76 Line Corrosion Lt. Deposits. 70 2209 0 0.09 37 7 2.74 Line Corrosion Lt. Deposits. 71 2241 0 0.09 35 7 2.76 Line Corrosion Lt. Deposits. 72 2273 0 0.09 35 6 2.79 Line Corrosion Lt. Deposits. 73 2304 0 0.10 39 6 2.76 Line Corrosion Lt. Deposits. 74 2336 0 0.08 31 6 2.79 Line Corrosion Lt. Deposits. 75 2366 () 0.08 32 a 2.81 Line Corrosion Lt. Deposits. 76 2398 0 0.09 35 6 2.78 Line Corrosion Lt. Deposits. 77 2430 0 0.08 30 4 2.76 Line Corrosion 78 2461 0 0.11 45 4 2.85 Line Corrosion Lt. Deposits. 79 2493 0 0.06 24 6 2.82 Line Corrosion Lt. Deposits. 80 2525 0 0.11 41 7 2.80 Line Corrosion Lt. Deposits. 81 2557 0 0.09 36 6 2.83 Line Corrosion Lt. Deposits. 82 2588 0.09 0.08 33 6 2.77 Line Corrosion Lt. Deposits. 83 2620 () 0.09 33 7 2.79 Line Corrosion Lt. Deposits. 84 2651 0 0.06 25 a 2.82 Line Corrosion Lt. Deposits. 85 2683 () 0.08 33 ß 2.77 Line Corrosion Lt. Deposits. 86 2714 0 0.09 37 7 2.79 Line Corrosion Lt. Deposits. 87 2746 0 0.10 39 6 2.80 Line Corrosion 88 2777 0 0.11 44 10 2.83 Line Corrosion 89 2809 0 0.08 30 7 2.80 Line Corrosion Lt. Deposits. 90 2840 0 0.09 36 6 2.80 Line Corrosion Lt. Deposits. 91 2872 0 0.10 38 7 2.83 Line Corrosion Lt. Deposits. 92 2903 0 0.09 35 6 2.81 Line Corrosion Lt. Deposits. 93 2934 0 0.11 43 5 2.81 Line Corrosion Lt. Deposits. 94 2965 0 0.09 35 5 2.81 Line Corrosion 95 2997 0 0.11 42 6 2.81 Line Corrosion Lt. Deposits. 96 3029 0 0.10 39 5 2.79 Line Corrosion Lt. Deposits. 97 3060 0 0.08 31 6 2.82 Line Corrosion Lt. Deposits. I Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE-8rd Well: 1 D-114 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 2.992 in Country: USA Survey Date: July 29,2005 Joint Jt. Depth Pen. Pen. Pen. lvlC'tal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (I ns. ) %, (Ins.) 0 50 100 98 3092 0 0.09 36 5 2.84 Line Corrosion 99 3124 0 0.09 35 6 2.83 Line Corrosion Lt. Deposits. 100 3155 0 0.10 38 6 2.80 Line Corrosion Lt. Deposits. 101 3187 0 0.11 42 4 2.80 Line Corrosion Lt. Deposits. 102 3219 0 0.11 44 S 2.76 Line Corrosion Lt. Deposits. 103 3250 0 0.14 57 7 2.76 Line Corrosion Lt. Deposits. 104 3282 0 0.08 31 S 2.82 Line Corrosion Lt. Deposits. 105 3314 0 0.09 35 5 2.78 Line Corrosion Lt. Deposits. 106 3346 0 0.09 34 6 2.80 Line Corrosion Lt. Deposits. 107 3377 0 0.10 40 4 2.78 Line Corrosion Lt. Deposits. 108 3409 0 0.09 34 6 2.79 Line Corrosion Lt. Deposits. 109 3441 0 0.08 32 4 2.82 Line Corrosion Lt. Deposits. 110 3472 0 0.08 33 5 2.85 Line Corrosion 111 3504 0 0.09 36 5 2.82 Line Corrosion Lt. Deposits. 112 3536 0 0.08 33 :; 2.84 Line Corrosion 113 3567 0 0.08 32 4 2.86 Line Corrosion Lt. Deposits. 114 3599 0 0.09 37 5 2.80 Line Corrosion Lt. Deposits. 115 3630 0.06 0.08 31 :3 2.79 Line Corrosion Lt. Deposits. 116 3662 0 0.11 42 S 2.79 Line Corrosion Lt. Deposits. 117 3694 0 0.09 35 5 2.78 Line Corrosion Lt. Deposits. 118 3725 0 0.08 32 4 2.81 Line Corrosion Lt. Deposits. 119 3757 0 0.09 36 :; 2.78 Line Corrosion Lt. Deposits. 120 3789 0 0.09 35 4 2.78 Line Corrosion Lt. Deposits. 121 3820 0 0.09 36 5 2.79 Line Corrosion Lt. Deposits. 122 3852 0 0.09 34 6 2.81 Line Corrosion 123 3883 () 0.09 36 6 2.81 Line Corrosion Lt. Deposits. 124 3914 0 0.09 36 5 2.81 Line Corrosion Lt. Deposits. 125 3946 0 0.09 37 5 2.82 Line Corrosion Lt. Deposits. 126 3978 0 0.10 39 6 2.81 Line Corrosion Lt. Deposits. 127 4009 0 0.08 32 6 2.83 Line Corrosion Lt. Deposits. 128 4041 0 0.08 33 6 2.82 Line Corrosion Lt. Deposits. 129 4072 0 0.09 35 ¡- 2.81 Line Corrosion Lt. Deposits. .) 130 4104 0 0.10 38 7 2.79 Line Corrosion Lt. Deposits. 131 4136 0 0.10 37 4 2.77 Line Corrosion Lt. Deposits. 132 4167 0 0.09 35 5 2.78 Line Corrosion Lt. Deposits. 133 4199 0 0.09 35 6 2.79 Line Corrosion Lt. Deposits. 134 4230 0 0.09 35 5 2.84 Line Corrosion Lt. Deposits. 135 4262 0 0.10 38 5 2.84 Line Corrosion Lt. Deposits. 136 4294 0 0.10 38 7 2.83 Line Corrosion Lt. Deposits. 137 4325 0 0.10 41 4 2.87 Line Corrosion Lt. Deposits. 138 4357 0 0.09 35 6 2.84 Line Corrosion Lt. Deposits. 139 4387 0 0.11 44 8 2.82 Line Corrosion Lt. Deposits. 140 4419 0 0.11 42 7 2.85 Line Corrosion Lt. Deposits. 141 4450 0 0.10 38 6 2.84 Line Corrosion 142 4482 0 0.10 40 10 2.85 Line Corrosion Lt. Deposits. 143 4513 0 0.13 52 4 2.88 Line Corrósion 144 4545 0 0.10 37 5 2.85 Line Corrosion Lt. Deposits. 145 4577 () 0.10 41 5 2.85 Line Corrosion Lt. Deposits. 146 4608 0 0.15 59 6 2.85 Line Corrosion Lt. Deposits. 147 4640 0 0.11 43 7 2.87 Line Corrosion Lt. Deposits. I Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 EUE-8rd 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Meté11 Min. No. (Ft.) Upset Body 0/0 Loss I.D. (Ills. ) (Ins.) %) (Ins.) 148 4671 0 0.10 41 6 2.86 149 4703 0 0.11 44 4 2.85 150 4734 0 0.10 41 () 2.84 151 4766 0 0.10 40 S 2.84 152 4797 () 0.13 51 5 2.87 153 4828 0 0.13 50 4 2.84 154 4860 0 0.11 42 a 2.83 155 4891 0 0.12 45 6 2.89 156 4921 0 0.12 47 4 2.87 157 4953 0 0.12 45 6 2.86 158 4984 0 0.12 46 4 2.90 159 5014 0 0.13 52 4 2.89 160 5045 0 0.12 49 5 2.89 161 5076 o.on 0.12 49 4 2.89 162 5107 0 0.12 45 4 2.90 163 5138 0 0.12 47 4 2.91 164 5170 0 0.12 47 4 2.92 165 5201 0 0.14 56 5 2.89 166 5233 0 0.14 54 7 2.89 167 5264 0 0.12 48 5 2.89 168 5296 0 0.14 55 8 2.90 169 5326 0 0.10 39 <) 2.89 169.1 5357 0 0.10 40 6, 2.92 169.2 5372 0 0 0 0 N/A 169.3 5378 0.06 0.12 46 5 2.94 170 5393 0.07 0.11 43 6 2.91 170.1 5424 0 0.04 15 2 2.90 170.2 5430 0 0 0 0 2.81 170.3 5432 0.08 0.06 25 4 2.90 171 5438 0.12 0.13 49 7 2.88 171.1 5469 0.09 0.11 44 10 2.91 171.2 5475 0 0 0 0 N/A 171.3 5489 0.06 0.13 51 8 2.83 171.3 5495 0 0.13 52 5 2.91 172 5505 0.05 0.12 47 7 2.91 Well: Field: Company: Country: Survey Date: 1D-114 KUPARUK CONOCOPHILLlPS ALASKA INC USA July 29,2005 Comments Damage Profile (% wall) o 50 100 Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. Line Corrosion Line Corrosion Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line Corrosion Line Corrosion Lt. Deposits. Line corrosion. PUP Line Corrosion. GLM 1 (Latch @ 2 :00) PUP Line Corrosion. Lt. Deposits. Line Corrosion PUP Shallow Line Corrosion. OS NIPPLE PUP Line Corrosion Line Corrosion Lt. Deposits. PUP Line Corrosion Lt. Deposits. SEAL PUP Line Corrosion Lt. Deposits. PUP Line Corrosion Lt. Deposits. Line Corrosion Lt. Deposits. p. II. ... ... ... ... I. ..1 1!11 ;11 MIl 11 Page 4 . Penetration Body !~ Metal Loss Body cId.·.-·-···-······ . .. .----. . .·tS. IJ· PDS Report Cross Sections Well: Field: Company: Coun try: Tubing: 1 0-11 4 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 29,2005 MFC 24 No 00387 1.69 24 J. Thompson Cross Section for Joint 146 at depth 4611.57 ft Tool speed = 54 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 55 0 Finger 5 Penetration = 0.15 ins Line Corrosion 0.15 ins = 59% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~s. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-114 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 29, 2005 MFC 24 No 00387 1.69 24 J. Thompson Cross Section for Joint 103 at depth 3258.01 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 93 % Tool deviation = 82 0 Finger 3 Penetration = 0.144 ins Line Corrosion 0.14 ins = 57% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ..1_--', . ·\5.·.·, ~ B' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-11 4 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-BO EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 29, 2005 MFC 24 No 00387 1.69 24 J. Thompson Cross Section for Joint 68 at depth 2146.52 ft Tool speed == 50 Nominal 10 == 2.992 Nominal 00 == 3.500 Remaining wall area == 100 % Tool deviation == 86 0 Finger 17 Projection == -0.064 ins Deposit Min 10 == 2.73 ins. HIGH SIDE == UP Cross Sections page 3 :Ids ~. .~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-114 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 EUE-8rd Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 29,2005 MFC 24 No 00387 1.69 24 J. Thompson Cross Section for Joint 70 at depth 2210.75 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 84 0 Finger 8 Projection = -0.068 ins Deposit Min 10 = 2.74 ins. HIGH SIDE = UP Cross Sections page 4 .PHILLlPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEutvI COMPANY 1D-114 GasUft måeltÐummy Valve 1 (5372-5373, 00:4.725) T ubirg (0.6477, 00:3.500, 10:2.992) NIP (543)..5431, 00:3,500) Production (0.6477, 00:5,500, Wt:15.50) SEAL (5476-5477, 00:5,000) Production (5477-6259, 00:3.500, Wt:9.30) Perf (5580-5612) Perf (5650-5678) Perf (5684-5688) Perf (5701-5707) Perf (5717 -57'12) Perf (5748-5754) Perf (5776-5781) Perf (5790-5796) Perf (5824-5836) Perf (5850-5862) PLUG (6144-6145, 00:2.992) -"till - - ;;~'III'~~_~J~+\:~1\;ïnr~R~ f l;q~ 1 ~:: :'ciJ J1.~l~,I\¡¿~\,,~lli''ßJ~'ö1I~ J ..\~ ¡I.;;! Well Type: INJ Orig 8/28/1998 Completion: Last W/O: Ref Log Date: TO: 6270 ftKB Max Hole Angle: 68 deg @ 2596 Zone Status Ft SPF Date Type Comment VVS D 32 4 5/3/1999 IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP, 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient 12 4 5/1/1999 IPERF 2.5"HC3IJUJ HMXDP. 180 deg phase +- 90 deg orient 12 4 5/1/1999 IPERF 2.5" HC 31J UJ HMX DP. 180 deg phase +- 90 deg orient API: 500292290800 SSSV Type: NONE Annular Fluid: 3% KCI Reference Log: Last Tag: 6130 Last Tag Date: 1/4/2000 Casing String - ALL Description Conductor Production Production Tubing String - Tubing Size I Top 3.500 0 Perforations Summary Interval TVD 5580 - 5612 3625 - 3654 Size 16.000 5.500 3.500 I Bottom 5477 5650 - 5678 3689 - 3714 VVSB 5684 - 5688 3719 - 3723 VVSB 5701 - 5707 3735 - 3740 V\IS A4 5717 - 5722 3749 - 3754 V\IS A4 5748 - 5754 3778 - 3783 V\IS A3 5776 - 5781 3803 - 3808 V\IS A3 5790 - 5796 3816 - 3821 V\IS A3 5824 - 5836 3847 - 3858 V\IS A2 5850 - 5862 3870 - 3881 V\IS A2 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 5372 3440 CAMCO KBG-2-9 CAMCO Other l)lugs, equip., etc.: - JEWELRY Depth TVD Type 5430 3491 NIP 5476 3532 SEAL 6144 4139 PLUG VMfr KRU 1 D-114 Angle @ TS: deg @ Angle @ TO: 23 deg @ 6270 Rev Reason: Perf info by ImO Last Update: 8/15/2002 Top o o 5477 Bottom 121 5477 6259 TVD Wt Grade Thread 121 62.58 H-40 Welded 3532 15.50 L-80 BTC-MOO 4245 9.30 L-80 EUE-8rd Grade Thread L-80 EUE-8rd TVD 3532 Wt 9.30 28 4 5/3/1999 4 4 5/2/1999 6 4 5/2/1999 5 4 5/2/1999 6 4 5/1/1999 5 4 5/1/1999 6 4 5/1/1999 V Type V aD Latch Port TRO DVlY o Date Run 8/27/1998 Vlv Cmnt 1.0 INT 0.000 Description CAMCO DS NIPPLE W/ NOGO BAKER GBH-22 LSA Set Bridge Plug CIBP 5/1/99 ID 2.812 4.000 0.000 Sperry-Sun Drilling Services LIS Sca~ %ility Wed Oct 14 13:13:20 1998 '. _j Reel Header Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SAK) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80341 S. BURKHARDT D. BREEDEN 1ST STRING 1D-114 500292290800 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-OCT-98 MWD RUN 2 AK-MM-80341 M. SABERI D. BREEDEN 23 liN 10E 46 597 .00 112.10 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING ~ 3RD STRING PRODUCTION STRING REMARKS: 8.504 6270.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH MIKE WERNER OF ARCO ALASKA, INC. ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA P~AY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY P~LASE-4 (EWR4) . 4. WELL 1D-114 REACHED A TOTAL DEPTH OF 6270'MD, 4255'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 82 0 6229.5 RPM 82 0 6229.5 RPS 82 0 6229.5 RPX 82 0 6229.5 GR 89 0 6237.0 FET 121 5 6229.5 ROP 123 0 6270.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUI% _.O MERGE TOP MERGE BASE 1 121.0 3602.0 2 3602.0 6270.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Min Max DEPT 82 6270 GR 10.5976 149 RPX 1.966 2000 RPS 2.0175 2000 RPM 1.4536 2000 RPD 1.1406 2000 ROP 13.0887 660.046 FET 0.0749 9.5032 Mean Nsam 3176 12377 69.7468 12297 55.1429 12296 72.8719 12296 74.2617 12296 115.917 12296 300.285 12295 0.338197 12217 First Reading 82 89 82 82 82 82 123 121.5 Last Reading 6270 6237 6229.5 6229.5 6229.5 6229.5 6270 6229.5 First Reading For Entire File .......... 82 Last Reading For Entire File ........... 6270 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name .............. ~'SLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLIMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NTJMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 82.0 3562 5 RPM 82.0 3562 5 RPS 82.0 3562 5 RPX 82.0 3562 5 GR 89.0 3570 0 FET 121.5 3562 5 ROP 123.0 3603 0 $ LOG HEADER DATA DATE LOGGED: 24-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 68.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AlqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3602.0 121.0 3602.0 TOOL NUMBER P1038CRG6 P1038CRG6 8.500 8.5 LSND 9.60 221.0 9.3 400 5.4 7.000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.210 7.500 6.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 t 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 32.8 Name DEPT GR RPX RPS RPM RPD ROP FET 2 1 33 0 Min 82 10 5976 3 8989 3 0904 4675 1406 0639 0749 First Max Mean Nsam Reading 3603 1842.5 7043 82 132.416 65.8811 6963 89 2000 89.387 6962 82 2000 120.333 6962 82 2000 123.218 6962 82 2000 196.163 6962 82 640.539 322.458 6961 123 3.175 0.252595 6883 121.5 Last Reading 3603 3570 3562.5 3562.5 3562.5 3562.5 3603 3562.5 First Reading For Entire File .......... 82 Last Reading For Entire File ........... 3603 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3563.0 6229 5 RPD 3563.0 6229 5 RPM 3563.0 6229 5 RPS 3563.0 6229 5 RPX 3563.0 6229 5 GR 3570.5 6237 0 ROP 3603.5 6270 0 $ LOG HEADER DATA DATE LOGGED: 25-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 23.3 MAXIMUM ANGLE: 67.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 6270.0 3602.0 6270.0 TOOL NUMBER P1038CRG6 P1038CRG6 8.500 8.5 LSND 9.60 235.0 MUD PH: YfUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M3LX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined AJ~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.6 400 6.2 6.000 3.316 5.000 4.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 40.6 First Name Min Max Mean Nsam Reading DEPT 3563 6270 4916.5 5415 3563 GR 20.0138 149 74.7931 5334 3570.5 RPX 1.966 164.917 10.447 5334 3563 RPS 2.0175 189.052 10.9255 5334 3563 RPM 1.4536 178.827 10.3638 5334 3563 RPD 1.6462 188.473 11.18 5334 3563 ROP 13.0887 660.046 271.349 5334 3603.5 FET 0.0812 9.5032 0.448659 5334 3563 Last Reading 6270 6237 6229.5 6229.5 6229.5 6229.5 6270 6229.5 First Reading For Entire File .......... 3563 Last Reading For Entire File ........... 6270 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Vers~ion Number .......... 0.0 Date of Generation ........ ~/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File
