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Home My WebLink About195-083 %,or Tit • \��X77 s, THE STATE Alaska Oil and Gas i o f eLAS II(A Conservation Commission fifth-7:-_-:-.7:4_,,_ :..+ ao:..�•.-+.... ........_. 333 West Seventh Avenue '4,;11.4-1-111*--r Anchora e, Alaska 99501-3572 GOVERNOR BILL WALKER g * Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis SCANNED OCT 3 12016 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-26RD Permit to Drill Number: 195-083 Sundry Number: 316-386 Dear Mr. Golis: 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/6i*,/c.,__ Cathy 7Foerster Chair DATED this - day of August, 2016. RBDMS L`' AUG - 2 2016 • 0RECEIVED . STATE OF ALASKA JUL ` X016 // ALASKA OIL AND GAS CONSERVATION COMMISSION .0-7-s `e861, APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0• Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory 0 Development 0• 195-083 ` 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20097-04 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 0 J Trading Bay Unit K-26RD . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil&Middle Kenai G 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): 11,078 ' 9,967 10,707 ` 9,600 ' 2,585 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 350' 24" 350' 349' Surface 2,938' 13-3/8" 2,938' 2,716' 3,450 psi 1,950 psi Intermediate Production 8,672' 9-5/8" 8,672' 7,712' 10,900 psi 7,950 psi Liner 2,632' 7" 11,031' 9,923' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,105-10,744 . 8,999-9,637 3-1/2" 9.2#/L-80 8,650 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Twin Set Hyd Pkr&TE-5 SSSV , 383'(MD)383'(ND)&364'(MD)364'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/1/2016 OIL ❑ WINJ ❑ WOSPL ❑ Suspended 0 • 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 3L.-J Phone (907)777-8356 Date 1 l Z S I l t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 \Lt. - 3� k Plug Integrity 0 BOP Test 1. Mechanical Integrity Test ❑ Location Clearance ❑ Other: Q 3 O t) s .S r - Post Initial Injection MIT Req'd? Yes ❑ No ❑ at) I`3 ,../-4....7`. ` Spacing Exception Required? es ❑ • P. Subsequent Form Required: it) L/ 7 r ``,-,e 6 91 x APPROVED BY Approved by: ITS • COMMISSIONER THE COMMISSION Date: 9-1-14 fa 7- 1g- 7/;7 721-4, Ri6a1PNAtalid Submit Form and Form 10-403 Revised 11/2015O for 12months from the date o approval. Attachments in Duplicate RBDMS wAIJG - 2_2.016 . • Well Work Prognosis Well: K-26rd Hilcorp Alaska,LLC Date: 06/23/2016 Well Name: K-26rd API Number: 50-733-20097-04 Current Status: ESP Producer Leg: Leg#4 (NW corner) Estimated Start Date: September 01, 2016 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 195-083 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Trudi Hallett (907)777-8232 (0) (907)301-6657 (M) Current Bottom Hole Pressure: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.45 ppg)06/05/2009 static BHP Maximum Expected BHP: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.45 ppg)06/05/2009 static BHP Maximum Potential Surface Pressure:2,585 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Note:This is a no-flow Well(11/19/2014) Brief Well Summary K-26rd is a comingled G-Zone/ Hemlock ESP. This workover will pull the current completion and plug the well for a sidetrack./ Last Casing Test: 10/30/2014 8,940' 1500 psig for 30 minutes charted.Casing leaks observed below 8,940' Procedure: 1. Skid Rig into position above K-26rd 2. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (N. e: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Circulate hydrocarbons from well to production—Work. er fluids will be FIW. n 4. POOH laying down completion. � .,".5� ,,'- 5. RIH with bit and scraper to top of liner at±8,399' irculate clean. POOH. I3 6. RIH with cement retainer and set at±8,350' t • We request a waiver to 20AAC25. .a1c1d to set the retainer+/-600' above the known leak at 8,940'covering both the '.sing leaks and the liner top. 7. Sting into cement retainer 8. RU cementing equipment and pu • ±90 barrels Class G cement into 7" liner to plug existing perforations. Unsting from retai•er and circulate hole clean. 9. POOH 10. Pressure Test casing to 1,5I d psig for 30 minutes and chart. 11. RU e-line and RIH w/CIB' to±6,000'±CIBP 5'above casing connection. 12. RD e-line. 13. ***Remaining Procea ure to be included on the Permit to Drill for the sidetrack*** t�e(1 U^Aig q as l't�-r'l P�o01vice� Attachments: �onGv�. `' 1. Well Schematic Current -rllgr- Aad (Arid 7,0 nonvl,',71� v� O/, kil2r� 2. Well Schematic Proposed op VertCJ jp CST ©c lir �4`yi 3. Wellhead Schematic Current T Ivo / 4. BOP Drawing ��o d✓eti& ei'r l,eaNykt�(9, tq/4f Ar 40,04 0, � 4 5. Fluid Flow Diagrams 03- Boo o ,bvl- 146 drcrl" � t ;� W I(y 6. RWO Sundry Revision Change Form 6 eai�y �!' ,,,�,r4 q 1ro►�'{�Gvh Of l D • 1W 4"4 7-4& well �� !'eo��:ll �iov�� G��o„ ter yc� fccol"r' f�o� ritly port/0A of- ire �'el,• • • Well Work Prognosis Well: K-26rd • Hi'carp Alaska,11,1,CDate: 06/23/2016 Well Name: K-26rd API Number: 50-733-20097-04 Current Status: ESP Producer Leg: Le rner) Estimated Start Date: September 01,2016 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 195-083 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Trudi Hallett (907)777-8232 (0) (907)301-6657(M) Current Bottom Hole Pressure: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.45 ppg)06/05/2009 static BHP Maximum Expected BHP: 3,659 psi @ 12,328'(9,451'TVD) 0.387 lbs/ft(7.45 ppg)06/05/2009 static BHP Maximum Potential Surface Pressure:2,585 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Note:This is a no-flow Well(11/19/2014) Brief Well Summary K-26rd is a comingled G-Zone/ Hemlock ESP. This workover will pull the current completion and plug the well for a sidetrack. Last Casing Test: 10/30/2014 8,940' 1500 psig for 30 minutes charted.Casing leaks observed below 8,940' S�fJe-c..�i c Procedure: 1. Skid Rig into position above K-26rd 300D to 2. ND Wellhead, NU BOP and test to 250psi low/ psi high.(Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Circulate hydrocarbons from well to production—Workover fluids will be FIW. 74 4. POOH laying down completion. 7-21-1‘, , 5. RIH with bit and scraper to top of liner at±8,399',circulate clean. POOH. 6. RIH with cement retainer and set at±8,350' • We request a w4tik•r to 20AAC25.112.a1c1d to set the retainer+/-600'above the known leak at 8,940'covering both the casing leaks and the liner top. 7. Sting into cement retainer 8. RU cementing equipment and pump±90 barrels Class G cement into 7" liner to plug existing perforations. Unsting from retainer and circulate hole clean. 9. POOH 2,060 ' P�" fi- A 76 Q, f- 10. Pressure Test casing to 1, sig for 30 minutes and chart. P^-fl C-Gk 11. RU e-line and RIH w/CIBP to±6,000'±CIBP 5'above casing connection. 12. RD e-line. 13. PU whipstock and mills and RIH to CIBP. -rt14. Orient whipstock and set at 45 degrees right of high side. 5"-PD 7 ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** ------ General sequence of operations pertaining to drilling procedure: (informational only) 15. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. 16. PU directional BHA and TIH to window. 17. Swap well to 9.5 ppg oil based drilling mud 18. Drill and complete new production hole. Crb • • Well Work Prognosis • Well: K-26rd Hilwrcp Alaska,LLC. Date: 06/23/2016 19. Perforate per program 20. Run new completion Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form 4 . •McArthur River Field . 111 Well: K-26RD SCHEMATIC Last Completed: 11/06/2014 Hilcorp Alaska,LLC PTD: 195-083 RKB to Sea Level(MSL)=100' KB 35' CASING DETAIL SIZE WT GRADE CONN TOP BTM. j.i 24" 186 X-56 Weld 0 350' 1.11117-11:01' : 13-3/8" 68 K-55 BTC 0 2938' X 9-5/8" 53.5 P110 BTC 0 8672' 7" 29 L-80 BTC 8399' 11031' • " TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf 8,650' JEWELRY DETAIL Depth Depth No (MD) (TVD) ID Item > 1*- 1 364' 364' 2.813 TE-5 SSSV 2 383' 383' 3.00 Twin Seal Hyd Packer(Packer has not �;,' been set) 3 407' 407' 2.813 X-Nipple 4 419' 419' 2.810 GLM w/Orifice 1. 5 8,650' 7,692' - Discharge:Bolt-On 6 8,651' 7,693' - Pump(x5)Summit 400 Series 7 8,765' 7,785' - Seals ,f 8 8,782' 7,799' - Motor(x2)Summit 456 Series - 9 8,850' 7,853' - Centralizer/Anode Ili r PERFORATION DETAIL Btm le, Zone Top(MD) Btm(MD) Top(TVD) (TVD) Condition Date f^ G-5 10,105' 10,195' 8,999' 9,089' ;*. G-5 10,124' 10,191' 9,019' 9,086' Open 11/02/14 �.i H-1 10,300' 10,328' 9,194' 9,222' /`•` H-1 10,304' 10,326' 9,199' 9,221' Open 11/02/14 1,111Ut H-2 10,368' 10,410' 9,262' 9,304' H-2 10,378' 10,438' 9,273' 9,333' Open 11/02/14 s„< H-4 10,420' 10,440' 9,314' 9,334' L H-4 10,480' 10,512' 9,374' 9,405' 'Lil .- H-3 10,500' 10,506' 9,395' 9,401' Open 11/02/14 • H-4 10,533' 10,580' 9,426' 9,473' H-4 10,538' 10,587' 9,433' 9,482' Open 11/02/14 -"" G-5 H-4,5,6 10,602' 10,702' 9,495' 9,595' ' ----'7', H-4 10,606' 10,616' 9,501' 9,511' Open 11/02/14 HB-1 H-5 10,630' 10,655' 9,525' 9,550' Open 11/02/14 - HB-2 H-6 10,718' 10,744' 9,611' 9,637' .,,k; HB-3 ri _ 11, _ HB-4 HB-5 • ='• HB-6 TD=11,078' PBTD=10,933' Max Hole Angle=34° Updated By:JLL 12/05/14 • McArthur River Field Well: K-26RD II 0 PROPOSED Last Completed: Future fIileorp Alaska,LLC PTD: 195-083 RKB to Sea Level(MSL)=100' KB 35' CASING DETAIL i SIZE WT GRADE CONN TOP BTM. "A 24" 186 X-56 Weld 0 350' ;r 13-3/8" 68 K-55 BTC 0 2938' .f 9 5/8" 53.5 P110 BTC 0 8672' 7" 29 L-80 BTC 8399' 11031' 3 TUBING DETAIL 01 N/A ef Wil JEWELRY DETAIL No Depth Depth ID Item (MD) (TVD) 1 ±6,000' ±5,361' CIBP(set for whipstock) 2 ±8,350' ±7,440' Cement Retainer 04 e PERFORATION DETAIL CIBP , Top Btm Top Btm Status ±6,000' i ( -4:71 ; W_ Zone (MD) (MD) (TVD) (TVD) Date = G-5 10,105' 10,195' 8,999' 9,089' Cement G-5 10,124' _10,191' 9,019' 9,086' 11/02/14 Retainer - "` H-1 10,300' 10,328' 9,194' 9,222' ±8,350' r7 "`` >`„I of H-1 10,304' 10,326' 9,199' 9,221' 11/02/14 H-2 10,368' 10,410' 9,262' 9,304' H-2 10,378' 10,438' 9,273' 9,333' 11/02/14 H-4 10,420' 10,440' 9,314' 9,334' H-4 10,480' 10,512' 9,374' 9,405' Cemented I. & H-3 10,500' 10,506' 9,395' 9,401' 11/02/14 H-4 10,533' 10,580' 9,426' 9,473' H-4 10,538' 10,587' 9,433' 9,482' 11/02/14 H-4,5,6 10,602' 10,702' 9,495' 9,595' G-5 H-4 10,606' 10,616' 9,501' 9,511' 11/02/14 HB 1 H-5 10,630' 10,655' 9,525' 9,550' 11/02/14 H-6 10,718' 10,744' 9,611' 9,637' HB-2 HB-3 HB-4 7 n „ o 7! i3PP" HB-5 -�, HB-6 3 .. y you 3C, A .o 171 = $Y pec. TD=11,078' PBTD=10,933' Max Hole Angle=34° Updated By:JLL 07/19/16 • • King Salmon Platform • /I K-26RD Hilrarp alulka_L(( 09/04/2014 King Salmon Tbg hanger,OCT-UH-TC-1A- K-26RD ESP,13 X 4'/ IBT lift and 24 X133/8 X95/8 X41/2 susp,w/4' Type HBPV profile,3/8 cont control line port BHTA,B-11-A0,4 1/16 5M FE IOW ul u,=1.un C\/lel 11111 Valve,Swab,WKM-M,41/16 5M FE,HWO,EE trim t—0---- T. • Valve,Wing,WKM-M,3 1/8 5M FE,w/ U�,,U gen!W fill oper,EE trim Valve,Wing,WKM-M,2 1/16 5M FE,HWO,AA trim L / N �1 J 1 r 1 T . rrn L u.). I 1.111.111111111 Valve,Master,WKM-M,4 1/16 5M �C FE,HWO,EE trim ° o n n' .. . . ,,,,,, , SRI RI lin IIIII 60)4 + Valve,Wing,CIW-FL,3 1/8 5M FE, ' HWO,EE trim Ea''�, i�O Adapter,OCT-A5-ESP,13 5/8 5M API hub ionX 4 1/16 5M stdd top,w/2-%control •1�� line exits,prepped w/OCT 400-4 pocket II „. All unihead annular valves, Unihead,OCT type 3,13 5/8 5M API . ® 2 1/16 5M FE OCT-20,HWO hub top X 13 3/8 BTC casing bottom, l=,...11_ '�,•�` �I! `.I�' w/1-2 1/16 5M SSO on lower section,1-2 1/16 5M SSO on middle S. section,3-2 1/16 5M SSO on upper _,�s i 0 section,IP internal lockpin assy ,/._��'t' Ili.�.: i `I'1�� Valve,OCT-20,3 1/8 2M FE, 1 Starting head,OCT,21'/<2M FE X- '� �� .- HWO 24”SOW,w/1-3 1/8 2M EFO,full 1 Mligli • , -I' set of lockpins 41 In 24', 3/8" 9 5/8" 4%" • •i King Salmon Platform . II2016 BOP Stack(Kuukpik) 06/22/2016 Hiharp:tlaeka.IAA. 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I ° o Ol, I Ol i O1 O1 O1 OlI•v,L, i i I I 1 0' 6' 6,' 44' d' go' 0' d' 4+' 01�101c1�1�1�10101 I I , 1 1 1 1 1 d p,l p,l yl 0.1 0,1 yl .! p,l 0.1 OIOIOIOI01oI 18181 O,o,O,O,o,o,O,O,o, O O O O O O O O O i v.1 Inl UIl U.I U.l Inl I4' ,nl v.1 ;01 ol;al of 01;01;01 1;01 Le) ---'1r-.1.&"17--'17.-17-7.17.1r--"Ir-"I It 1,1 IrlIelI44144144Irilfill r,l ,,/) U_ y 1 1 1 1 1 1 1 1 1 W a -,I r,!w,!.t ki!,o h r 1 331 a! 7 1 1 1 1 1 1 1 1 1 to a Ch o. i-•. a a • a. 1 ^/�„ o • Choke Manifold Valves 2 " To Shaker 3" Panic To Gasbuster 3 1/8" 2 1/16"O O 2 1/16" ty fili O 21/1 + 21/16" + /! 3 1/8" � © \`O I ea T © Q 2 1/16" + 2 1/16" Manual Choke �� Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C-2 N7 +, #11 ws • • Kuukpik 5 BOP Test Procedure Hilcorp nin.ka.r.i.c Attachment#1 Attachment #1 Hilcorp Alaska LLC. Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile&lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick(AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory(melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path,test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPS looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPs are not leaking. Test# 1= Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Saxon's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • • Kuukpik 5 BOP Test Procedure Haror,,,,►aGka,►.►.( Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/ upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Saxon's standard procedure 0 • c22 a) ._> / > � 2 / & O _ c \E 0o§ / 2k °/\ a�/ E ® • 0 St 2 • § 1 ef f / < k / CD / _0 � �' > -a ƒ ate / � .§ O 2 § 2.2 .( -0 e ■ o & � � L k k S % a)>- Ff z J Co f / CD o 0 .- o 13 til CD a _0 � O a. / c Li. Ce co � k m /« e c \ S -0 0 a) \ \ k Q) 2 E % ° m a) @ 0 k $ .a a a 4c 2 f / s_ \ /c a) »7 § c \ / / . Cl) 20 Cl) w so > -CO c a) @ § - a g 0 0_ a e ■ « / 0 00. . / 2 § f . E 0 . qQ § > 3R & i- \ n X m 15 / CD § / a. 0 s. 0 es % £ 2 it 0 ! ® .. / � _ c 0 ., a a / 4) E0 0a3 c u a_ 23 0 2 w \ 0 o_ • • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and ✓ initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist i work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- ~~po~Pages' r Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No.. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Dian~Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ Page 1 of 1 - 1/13/2010&u McMains, Stephen E (DOA) From: Kanyer, Christopher V [Chris.Kanyer@chevron.com] Sent: Wednesday, January 13, 2010 1:10 PM To: McMains, Stephen E (DOA); Aubert, Winton G (DOA) Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Tyler, Steve L Subject: Cancellation of open sundries/permits 'C) 83 After reviewing the following open permits to drill (form 10-401)/sundries (form 10-403) for Union Oil Company of California, it has been determined these open AOGCC permits/sundries should be cancelled: PTD Sundry API Well Name/Number 209-011 N/A 50-233-20025-00 Panthers 21-6-9 208-207 N/A 50-287-20026-00 Stegodon 24-6-8 209-058 N/A 50-733-20586-00 Trading Bay Unit M-08 197-067 308-252 50-733-20043-02 A-08RD2 2D4=117 308-269 50-733-20254-01 Trading Bay Unit K-18 1 n 1 Please .let me know if you have any questions. Thanks, Chris Kanyer ~• Technical Assistant Wellbore Maintenance Team Office: (907) 263-7831 Cell: (907) 250-0374 Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 JA~~ 4 ~D~ 1/13/2010 ALASSA OIL A1~TD GAS CO1~15ER~PA'TIO1~T COMMISSIOl~ Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 ~~'~~~ AU ~ ~ Z~~$ Anchorage AK 99519 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: McArthur River Field, Hemlock Oil Pool, TBU K-26RD ©~?J Sundry Number: 308-268 ~~~ Dear Mr. Brandenburg: 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 ~ day of August, 2008 Encl. p~ ~ ~ ~(~ STATE OF ALASKA `~~ ~ ~ ~~~~ ALA OIL AND GAS CONSERVATION COM~SION ~ APPLICATION FOR SUNDRY APPROVAL~.~~ ~ . 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver Other Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Conversion to Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ jet pump 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 195-083 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20097-04 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Tradin Ba Unit K-26RD - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0017594 Kin Salmon Platform 35` 100' MSL - McArthur River /Hemlock Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,078' ~ 9,970' 10,707' RKB SLM 9,600' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 374' 24" 374' 373' Surface 2,938' 13-3/8" 2,938' 2,718' 3450 psi 1950 psi Intermediate Production 8,559' 9-5/8" 9,359' 8,285' 10900 psi 7950 psi Liner 3,375' 7" 11,031' 9,923' 8160 psi 7020 psi Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" L-80 10,239' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FB-1 Packers / Baker TE-5 SSSV 10,000' / 309' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 11/6/2008 16. Well Status after proposed work: Commencing Operations: Oil ^~ ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature - ,, ~ Pho e 276-7600 Date 7/28/2008 '~ - ' ~ „.w... ~ r ~- C COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ O2~ Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ T ~ Other: w,~ (" -^~- ~.~ Subsequent Form Required: ~~ APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: r ~ R 1 G I N A t... - ~ ~~:. ~~~ ~ ~ ~ooB ~ 7.ZQ.~ Form 10-403 Revised 06/20 6 - Subry~t in Du lira • • Ch~oD Trading Bay Unit King Salmon Platform Well # K-26RD Current Completion 2/27/08 RKB to TBG Hanger = 32.85' CASING ANU TUBING DETAIL SIZE WT GRADF, CONN TOP BOTTOM 24" surf 350' 13-3/8" 68 K-55 BTC surf 2,938' 9-5/8" 53.5 P-110 BTC surf 8,672' 7" 29 L-80 BTC 8,399' 11,031' Tubing: 3-1 /2" 9.3 L-80 TDS surf 10,000' 3-1/2" 9.3 L-80 Butt 10,000' 10,239' NO. Death Item JEWELRY DETAIL 4-1/2" butt btm hanger with 3-1/2" TDS Xover 1. 309' Baker TE-5 SSSV (ID = 2.810") 2. 9,998' Baker locater with 10' seal assy 3. 10,000' Baker 7" FB-1 packer (4.000" ID), MOE 4.50" 4. 10,176' Baker 3-1/2" XN nipple (ID=2.650") 2.635" ?'? 5. 10,239' Baker shear out sub Gas Lift Information 1 2,379' 3-1/2" Camco MMM mandrel 2 4,132' 3-1/2" Camco MMM mandrel 3 5,289' 3-1/2" Camco MMM mandrel 4 6,333' 3-1/2" Camco MMM mandrel 5 6,844' 3-1/2" Camco MMM mandrel 6 7,356' 3-1/2" Camco MMM mandrel 7 7,866' 3-1/2" Camco MMM mandrel 8 8,438' 3-1/2" Camco MMM mandrel 9 9,043' 3-1/2" Camco MMM mandrel 10 9,586' 3-1/2" Camco MMM mandrel 11 9,944' 3-1/2" Camco MMM mandrel MAX HOLE ANGLE = 34° K-26RD Schematic PERFORATION DATA TOP BTM ZONE 10,105 10,195 GS 10,300 10,328 HB 1 10,368 10,410 HB2 10,420 10,440 HB4 10,480 10,512 HB4 10,533 10,580 HB4 10,602 10,702 HB4,5,6 10,718 10,774 HB6 ill (d 10,707'RK[3 SLM (2.25" bailer) 2008 REVISED: 2/27/08 - BCA PBTD = 10933' TD = 11078' RKB KB 35' OCTG Rotating Hours 24" 52 Rotating Hours 13-3/8" 268 Rotating Hours 9-5/8" 282 Rotating Hours 7" 24 Rotating Hours Tubing "0" Rotating Hours Size Type Wt/ Grade/ Conn ID Top Btm Cement Cement Sacks To 24" Structural 1 86#, X-56, Weld 22.313 0 374 Driven 13-3/8" . Surface . . 68# K 55, BTC 12.259 0 2938' 2050 Surf 9-5/8" .................................................. Surface .......................................................... 53.5#, P110, BTC ................................................._............................................ 10.625 ..................................... 800' ....................................... 9359' ........................................ ............................................ ............................................ 7• .... ............................... ................... ................... ..................Liner................... .......................................................... ..............._29#.,..._L-80.,....BTC................. ................................................................................................. ......_7.656....... ...................................... .......8399'........ ........................................ ....._1.1031..x....... ........................................ ...........1050............ ............................................ ..........8399'........... ............................................ Completion 3-1/2" Production 9.3#, L80, TDS Surf 10,000' In Casing 3-1/2" Production 9.3#, L80, Buttress 10000' 10,239' In Casing Completion Jewelry Detail # Depth Length ID OD Item 1 309' 2.810" Baker TE-5 SSSV, PB in top of Valve a 2379' GLV Drift 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover b 4132' GLV MIN ID 2.921" 3-1/2" Camco MMM Mandrel, Blank this workover c 5289' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover d 6333' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover e 6844' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover f 7356' 2.867" 3-1/2" Camco_MMM Mandrel, Blank this workover 7866' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover h _ 8438' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover i 9043' 2.867" 3-1/2" Camco MMM Mandrel, Blank this workover 9586' _ 2.867" __ 3-1/2" Camco MMM Mandrel, Blank this workover k 9944' 2.867' ' 3-1/2" Camco MMM Mandrel, Install communication ort 2 9998' _ Baker Locator Assembl 10' Seal Assembl 3 10,000' 4.000" Baker 7" FB-1 Packer, MOE 4.50" 4 10,176' 2.650" Baker 3-1/2" XN Nipple 2.635? _ 5 10,239' Baker Shear Out Sub Pro osed CT Jet Pump and Related Additional Subsu_rf_ace Equipment A 0 9975' 2" 2" CT HS-90 9975' 1' 2.750" 2"Coil Tubing Connector 9976' 7' 2.500" Pup Joint & x-over to Jet Pump _ 8 9983' 6' 2.280" Jet Pump Cavity C 9989' 15' 2.750" Locator Sub Seal Assembly __ . 9990" 15' 2.800" Top of PBR (approximately 16' Seal Bore f/ 15' movement, 2.750 Nominal - --- .. . D 10, 005' 5' 2.740" Packer Assembly (E-Line or Slickline Se_t/ Retrieve _ E 10, 010' 20' 2.500" Screen Assembly (20/40 Mesh) _ _ _ Perforation Data Dogl egs ZONE TOP BTM Shot Condition 4.5 764' G-5 10,105' 10,195' .-- 8999, 9089 TVD______ - -.. 3.5 7236' 4.16 7723' HB-1 10,300 10,328 ------ 9194,, 9222 TVD 7.05 8692' HB-2 10,368' 10,410' 9262, 9304 TVD 6.91 8876' HB-4 10,420' 10,440' 9314, 9334 TVD -- 10,480' 10,512' _ 9374, 9405 TVD _ 10,533' 10,580' 9426, 9473 TVD --- HB-4,5,6 10,602' 10,702' 9495, 9595 TVD_ _ HB-6 10 718' 10,744' 9611, 9637 TVD 1/23/2008: Fill tagged w/ 2.225 Bailer @ 10,707' RKB SLM FISH '10,720' Gas Lift Valve/ Perforation Gun Debris '10,750' 140' TCP Fired Assembl WBD K-26RD Proaosed doc JRN PBTD =10,933' TD = 11,078' MAX HOLE ANGLE = 34 ~' Chevron ~ading Bay Unit K-26RD CT Jet Pump Recompletion Revision #0: 07/24/2008 OBJECTIVE: Evaluate the suitability of the wellbore by Slickline work, E-line work to set the packer, Coil Tubing Unit to convey a Jet Pump at depth. Work to be completed with tree on below the swab valve. PROCEDURE SUMMARY: • PJSM -Prepare well for workover operations coordinating with platform operations. • PJSM - MI RU Slickline unit to mechanically LO TR-SSSV, Pull bottom live GL valve, circulate hole with filtered produced water -Change out "live" GL valves for "blanking" GL valves, set plug in X-profile nipple, pressure test production tubing, pull x-nipple plug, pull blanking valve from bottom GL mandrel, install large bore pocket protector. • PJSM -Circulate well bore with filtered produced water -monitor for 30 minutes for static loss rate -Install BPV into tree. • PJSM - ND Swab valve, install 4-1/16" ID coil tubing hanger head on production cross - NU swab valve - body pressure test assembly -Pull BPV - RU to circulate well with filtered produced water. • PJSM - MI RU E-Line -RIH -Set and Pressure Test CT PBR /packer w/ screens assembly in production tubing - RD E-line • PJSM - MORU CT Unit, perform AOGCC BOP test - PU Jet Pump Assembly - RIH w assembly -land into PBR, pressure test hanger seal. -Pull up, cut coil, install CT slip type connecter for hangar landing -Land slip type CT Hanger -Pressure test assembly - RD CT Unit • PJSM - RU Slickline Unit -Pull isolation sleeve -set standing valve -launch jet pump to cavity - RD slick line. • TURN OVER TO OPERATIONS -Operate well as CT conveyed Jet Pump artificial lifted oil producer. K-26RD WO Objective and Procedure Summary.doc REVISED BY: JRN 07/24/08 Ch+EVron ., DATE ]une 9, 2008 ~nCisco Castro Chevron Plorth~erica Exploration and Production 1`echnical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com To: AOGCC Mahnken, Christine R 333 W. 7th Ave. ste#i~~~NE~ JUN ~. ;~ 200 Anchorage, AK 99501 WELL LOG TYPE SCALE LOG DATE INTERVAL LOGGED RUN # B-LINE CD NOTES -LAS, PDS, DLIS COMPLETION TB ST A-25RD RECORD 5" 4-Mar-08 6660-7092 1 1 1 PDS COMPLETION TB ST A-01 RD RECORD 5" 5-Mar-08 5697-6140 1 1 PDS COMPLETION TBU K-18RD RECORD 5" 21-Feb-08 10800-12400 1 1 PDS ~ ~'~- ~3 COMPLETION TBU K-26 RD RECORD 5" 24-Feb-08 10303-10323 1 1 PDS PERFORATING TBU G-22 RECORD 5" 3-Ma -08 10122-10229 PS-2 i i -DLIS-PDS PERFORATING TBU M-17 RECORD 5" 16-Feb-08 7298-7381 PS-11 1 1 PDS PERFORATING TBU M-17 RECORD 5" 14-Feb-08 7296-7391 PS-9 1 1 PDS POSISET PLUG SETTING TBU M-17 RECORD 5" 11-Feb-08 6889-7430 PS-8 1 1 PDS PRESSURE TEMPERATURE TBU M-17 LOG 5" 15-Feb-08 5636-7398 PS-10 1 1 PDS DEPTH TBU M-17 DETERMINATION 5" 3-Feb-08 5782-7374.5 PS-7 1 1 PDS PERFORATING TBU M-17 RECORD 5" 19-Feb-08 5832-5856 PS-12 1 1 PDS POSISET PLUG SETTING TBU M-01 RECORD 5" 7-Jan-08 4792-5151 PS-2 1 PDS PERFORATING TBU M-01 RECORD 5" 18-Jan-08 4532-4580 PS-3 1 PDS HAPPY CEMENT BOND PDS, LAS, VALLEY B-12 LOG - SCMT 5" 18-Mar-08 3559-10315 1 1 1 DLIS COMPLETION PDS, DLIS, LRU C-01 RD RECORD 5" 14-Ma -08 4679-4759 1 1 FMA I 1 1 1 1 I 1 ( SRU 32A-15 SHOOT RECORD 5" 10-Mar-08 5554-5582 1 1 PDS ---~-__. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907: 263 7828. Received ~~ Date: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION hECEIVED MAR 2 0 2008 REPORT OF SUNDRY WELL OPERATION~aska (~18 Gas Cons. Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well^ 2. Operator Union Oil Company of California (UNOCAL) 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory^ 95-83 ' 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Senvice^ 6. API Number: 50-733-20097-04 7. KB Elevation (ft): 9. Well Name and Number: 100' KB above MSL ' K-26RD 8. Property Designation: ~ 10. Field/Pool(s): ADLKing Salmon Platform ,~h~ ~ 1' ~ ~ ~ - ~ "r- McArthur River/Hemlock/G Zone 11. Present Well Condition Summary: Total Depth measured 11,078' feet Plugs (measured) true vertical g,967' ' feet Junk (measured) 10,720' Effective Depth measured 10,707 feet true vertical 9600' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 350' 24" 350' 349' Surface 2938' 13-3/8" 2938' 2718' 3450 psi 1950 psi Intermediate Production 8672' 9-5/8" 8672' 7712' 10,900 psi 7950 psi Liner 2632' 7" 11,031' 9923' 7020 psi 8160 psi ~~,,~ APR ~ ~- 2008 Perforation depth: Measured depth: See SChenlBtlC True Vertical depth: See SChef'1'18tIC Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 10,239' Packers and SSSV (type and measured depth) 7" FB-1 pkr - 10,000' TE-5 SSSV - 309' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 58 188 800 psi 110 psi Subsequent to operation: 79 315 820 psi 100 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q ` Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~- ~ '~/ Phone 907-276-7600 Date 3/12/2008 Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ ~ ~\ d Original Only 111 IIIJJJ I N ~ ~ ~~~,~~ ~ ~-~6.. .~ i • Trading Bay Unit V N 0 ~A ~ 76 King Salmon Platform Well # K-26RD Current Completion 2/27/08 RKB to TBG Hanger = 32.85' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 24" surf 350' 13-3/8" 68 K-55 BTC surf 2,938' 9-5/8" 53.5 P-110 BTC surf 8,672' 7" 29 L-80 BTC 8,399' 11,031' Tubing: 3-1/2" 9.3 L-80 TDS surf 10,000' 3-1/2" 9.3 L-80 Butt 10,000' 10,239' NO. Denth Item JEWELRY DETAIL 4-1/2" butt btm hanger with 3-1/2" TDS Xover 1. 309' Baker TE-5 SSSV (ID = 2.810") 2. 9,998' Baker locater with 10' seal assy 3. 10,000' Baker 7" FB-1 packer (4.000" ID), MOE 4.50" 4. 10,176' Baker 3-1/2" XN nipple (ID=2.650") 2.63" ?? 5. 10,239' Baker shear out sub Gas Lift Information 1 2,379' 3-1/2" Camco MMM mandrel 2 4,132' 3-1/2" Camco MMM mandrel 3 5,289' 3-1/2" Camco MMM mandrel 4 6,333' 3-1/2" Camco MMM mandrel 5 6,844' 3-1/2" Camco MMM mandrel 6 7,356' 3-1/2" Camco MMM mandrel 7 7,866' 3-1/2" Camco MMM mandrel 8 8,438' 3-1/2" Camco MMM mandrel 9 9,043' 3-1/2" Camco MMM mandrel 10 9,586' 3-1/2" Camco MMM mandrel 11 9,944' 3-1/2" Camco MMM mandrel PERFORATION DATA TOP BTM ZONE 10,105 10,195 GS 10,300 10,328 HB1. 10,368 10,410 HB2 10,420 10,440 HB4 10,480 10,512 HB4 10,533 10,580 HB4 10,602 10,702 HB4,5,6 10,718 10,774 HB6 Il @ 10,707'RKB SLM (2.25" bailer) !008 K-26RD Schematic REVISED: 2/27/08 - BCA PBTD = 10933' TD = 11078' MAX HOLE ANGLE = 34° • q.~lft7l.tl\i~~1I®li ~V1~il~iit~~~Vl4 March 12, 2008 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit K-26RD, PTD 19~-083 Dear Mr. Myers: • SARAN PALiP1, GGVERN_OR 333 `J^J Th AV~hJUE, S'ui?F 1Ci0 ?hJCi-iOR:+GE,ALAS'r_ 9~5C;'-3~~9 PHOhJE i50'' ~7y.?-3"s ~U~ ~~~ ~ ~~~~ On March 5, 2008 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's King Salmon platform, Trading Bay Unit WeII K-26RD. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. This well demonstrated minor pressure build-up during the shut in phase of the test. Pressure dissipated rapidly with no sustained gas or fluid flow while open to atmosphere. The subsurface safety valve maybe removed from service in Well K-26RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a' subsequent no flow test. Please retain a copy of this letter on the King Salmon platform Sincerely, ---. ;, __J~_, James B. Regg ,' Petroleum Inspection Supervisor cc: Bob Fleckenstein Annular log P,~.I ' 'EXPL Afias #1 SUN 201.004 __ requested wlpM ............. BPX PBU B-33 PTD 93-018 1115/93 NIA .... N Y 12/14/98 3974 From BPXA Annular Injection Data Entry Screen; from B-36 -- BPX PBU B-,3~ PTD 96-065 6/4/96 NIA N N 0 Never utilized AAI EXPL Buffieheedl PTD95-063 12/i6/95 12/12/95 N__ Y Y '- 915/98 11148Annuterinjectionsummerof1998, ApprovalbyBEW AAI CRU CD1-01 __ SUN 99-046 6/26/99 3/12/99 N N N iY- 5221 from AA110113/200Oreport; auth. expired AAI CRU CD1-02 SUN---- !00.--~72 -- ~,AI CRU CD1-03 - SUN 199-120 1113/00 4/24/01 3399O ~ PPCO 4/24/2001 quarterly report~ soUrCewelis: CD1-43, CD1-31, CD1-30 PAl CRU CD1-04 SUN 200-117 __ __ Y A~I CRU CD1-05 SUN 199-128 4/2410i 386 from PPCO 4/24/01 quarterly report, soume w~l_l: CD1-O5 PAl CRU CD1-09 SUN 200-071 PAl CRU CD1-10 SUN 200-171 mci. w/p~d, need sundry prior to app~val AAI CRU CD1;13 SuN 199-052 8/9/99 ......... 189 fi.om AAI 1/24/2000 report AAI CRU CD1-16 __ SUN 199-O94 10/23/99 29050 from AA11119/2001. quarterly report AAI CRU CD1~19 SUN 99-023 4/20/99 4/20/99 34033 AAI CRU CD1-22 -~__--' PTD 97-252 4118/98 , NIA Y N N COntingent on data ~ubmlttal, bad surface cmt job - no annuler AAI CRU ;CD1-23 SUN 99-063 8/9/99 6/5/99 .y 10/13/00 33986 from AA110/13/2000 quarterly report; auth. expired. AAI CRU /CD1-24 '- SUN 99-026 -- .. AAI CRU CD1,25 SUN 200-08 ._ 33587 from AA110/13/2000 quarterly report AAI CRU CD1-28 SUN 99-088 10/4/99 -- AAI CR..~U. CD1.27 SUN 200.06 / Y 4/24/01 32814 from AAI 4/24/2001 qu___~e~ re rt, sourcewells:CD1-44_,CD1-1gA CD1-0G, CDI-~_______ AAI CRU CD1-28 __ SUN 200-199 ...............t PAl CRU CD1-30 SUN 200-132 . pAI - CRU CD1-30XX SUN 199-035 n/~'-' none ........ peter drilled ' PAl CRU CDiL31 -- sUI~I' 200-118 .... -- .... 71981 sundry approval #300-263, fm. PAl 4/24/01 report, source wells: CD1-14 pAl CEU CD1-32 SUN._ '199-104 ...... 33513 fromAAI 1t19/2001 quarterly report PAl CRU (~D.1-33 ....... SUN __ 200-2t2 w~request when drilling com_Dleted AAI CRU CD1.34 SUN 200-043 ..... 378 fr?.m AAI. 7/25/2000 qu~__~erly rep~ AAI CRU CD1-35 ___ SUN 99-038 .......... 317 fmmAA! l./24/2000_repo~ AAI cRu CD1-3~ .___ SUN 199-112 1/3/00 ...... i'---3___~.7 ~mAA!,.~/19/2001__~_p~t AAI --'-~RU CD1-37 SUN 99~.067._-6/~6/9~-''' 8/27/99 .............. ~ Y 10/13/00 32587 ~AA1.10/13/2000 report; auth..expired AAI CRU CD1-38 SUN 200.03 Y 4/2410_1~_ .20320 from PPCO 4/24/2.000 quarterly report, source wells; C._.~DI__~___.~_CD._I..._~_I~ CDl-19A AAI CRU CD1.39 SUN ~9~-_~80 9_/16/99 ..................... Y 10113/00-._ 31508 from AA! 10/13/2000 report[ auth, expired AAI CRU CD1-40 SUN . 99-044 ..... 6_/_1~_/99 .............. N_N- ........... .32877 from AA! 7/25/2000 quarterly .AAI CRU - CO1,41 SUN 200-017 ;AAI CRU CD1-42 SUN 199-119 1/3/00 ............................ 31334 fi.OmAA11119/2001 report =pAl ..... CRU CD1-43 SU____N~ .... _Z_007.106 31037 App. 300-241, from PPCO 4/24/200_1_ uu~.rl_y re rt~.ew__ells: C.D1.NQ1,..CDI-21 ~PAI CRU CD1-44 ..... SUN 200-055 __ 31928 from AAI 4/24/2001 repo~.source wells: CD_1-33, CD1-NQ1, CD1-10, CDI.28 IAAi~ .... _C_RU _ bbl-45 SUN 199-101 .... 32336 from AAI 1/19/2001 report ~,1 CRU ~"-~'~' §UN 200-027 .................... PAl CRU CD2-24 SUN 2.~01-095 301___2-1__86 ..................... AAI. CRU ~CD2-39 SUN 200-028 AA__L CRU =CD2-42 SUN 201-067 request ap~___.~lw_.~.d__a.L:~lcatlon ............ FORC EXPL coffee Creek #1 PTD 97-219 6/26/98 N/A Y ~Y ...... _Y_ ....... 4/16/98 _-- 1931 contingent on data submittal, in well file ~-~--- PBU D-30 PTD 96-026 3/22/96 N/A - N IY Y 5/20/96 5261 From BPXA Annular Injection Data Entry Sc~en ~-~--'--~ ~§~--1 D-31 P--~-~' ~--07i 5i1'-0-/;96 NIA N ' ~'- ~---- ~-- 2"--~8/97 - 150 from BPXA 1995 & 1998 corrected summaries ~-"---"! ~'-~'-" D-33 ...... PTD 98-036 4/20~---' NIA ~- ~ N _~ Y Y 6/11/96 488--1-From BPXA Annular Injection Data Entry Screen B__P_X___ PBU E-34 PTD 93.202 1/27/94 . _ NIA __ N_ ...... Y Y 2/26/97 9856 From BPXA Annular Ir~ection Date. Entry.Screen; from E-34, E__-38 ......... BPX PBU E-36 PTD 95-073 7/12/95 .. N/A 'N Y 12/14/98 9271 From BPXA Annular lng_ctS..on.Data Ent~ Screen .. . BPX PBU E-37 PTD 95-095 8/24/95 N/A N Y Y 2/21/97 4695 From BPXA 1995 & 1996 corrected summaries; from E-3g ~'15~'---' PBU ~"-~'~--~" _PTD ---..~_.~05 9115/95 NIA ............... 'N N 0 Neverutlllzed BPX PBU E-3g .PT_~_D. 95-126...!0/7/95 NIA N Y Y 2/26/97 2250: From BPXA~e~on~ En~~m E-39 BPX PBU F.33 PT, D.. __ i98-(X)3 411/96 NIA ..... __~ N . .......... Y Y 5/8/96 t468 From BPXA Annular tnej~_~tion Date. Entry Screen BPX PBU F.36 PTD 9__5_-1_96 .. 2R_/~6_ ...... NIA ........ N Y N 2/28/97 6983 from BPXA 1995 & 1996 corrected summaries BPX PBU G-04A PTD 95-163_. 12/4/95 N/A N Y 12/t4/98 __ 5937' _From BPXA Annular Injection Date Entry Screen '1 BPX ~BU G~21 .... PTD .9_5-i 5___.4__. 11112/95. _N/A_ ................ N____ .......Y_ ....... .Y.___ 12/1_____4_4/9~8 11430_ ~on ~Ent S~reen; from G-21 ~04A verbal approval from BEW 0/18/98; LOT plots tn well file, Sundry Approval for 2nd injection period. UNO mU G-22 SUN 75-0t6 7/18/75 3/22/00 N Y Y 8130KI0 7310 Fro: G.15, G.28RO G-26RD_ BPX- pBU H-35 SUN §5-~49 !!/9~.5_____ ........ N Y Y 2-~-~__.~'. ,,~6-~*~------~-~-q-~tw/sund~_____~.~._~to~-~-&~ BPX .. .P.B__U_.H-36 SU.N 95-155 11/26/95 N Y Y _. 2/28___.__/97,_._ 1452 le~ter request w/su__nd_, f~ e_gperator for H-35 & H-36 UNO TB_U_._... K-19 SUN ~4-008 . UNO __ ..T. BU . .K.-6RD .......... SUN 58.028 ~ 3/21/01 ._.~.~__-~'-~ ....................... ____14._7_17 Fm ema__jiLr-eport to Tom Maunder dated 7/2/01. Waste from K-13RD2 & K-lED2 :UNO TBU K.12RD SUN 76.057__~..~ UNO TBU K.19 SUN 74-008 2/9/01 ...~o - ~'Z~, LJN,O TBU K,,.25 ........ ~I..IN 8,5,.07,8 ........ ~,~*~i .- 0'~ J~ : - ....... : , , ....................................... Annular log MAR KU KBU 33-6 SUN 99-024I ' -----']- -- ~' .... not sure i~ annular requested ~et MAR KU KBU 42-7 SUN ¢Jgq325 I ~ _._ not Lt~m if annular requested yet ..... A~;~ EXPL Lone Creek ~tt SUN 98-084 10/12/98 ~9/14/98 ' Y Y '~ 12/1/98 ---'~2057 ~tingent~nl0-403, in well flle. {nJected volume ondai drtllin ___ AAI EXPL Meltwater Nmlh #2 SUN 199-130 , AAI EXP.L. Meltwater Nollh #2A SUN 2013-031 AAI EXPL ~ae~er Sou'dn #1 SUN 99-008 2/11/99 BPX MPU MPB-24 PTD 96-009 3/3/96 N/A -- N _ N _ [__. 1468 From BPXA Annula~ Injection Data Entr~ screen; Outer annulus left open BPX ....... MPU MPC.23 PTD 96016 6/2/96 N/A N yry, 1/25/97 2860'From C-23, C-28 (also 1905 bbis into C-25~ 5228 bbls into C-26) BPX MPU MPC-25 PTD 96-001 1/26/96 N/A N Y N 2/28/97 1905 from BPXA 1995 & 1996 com~cted summaries BPX MPU MPC-25A PTD 96-021 :5/4/96 N/A N Y Y 1/5/97 1905 From C-25, C-23 BPX MPU MPC-26 PTD 95.206 6/15FJ6 N/A N Y Y 12/19/96 5228 aPX MPU MPC-28 PTD 196-029 5/15/96 NIA - ~1--- ~-- Y- 11/'26/96 425 From [;-28, ' ' BPx MPU MPE-17 SUN 96-115 2/7/97 _ --- Y N 0 Neveru~ltlzed, no sund~ filed BPX MPU MPE-2.0 PTD 95-071 9/3/95 N/A N Y N 2/28/97 4863 from BPXA 1995 & 1996 corrected summaries .... BPX , MPU MPE-22 PTD 95-081 8/4/95 N/A N N 0 Never utilized BPX MPU MPE-23 PTD 954394 9/5/95 NIA N N 0 Never utir, zed E~px --- MPU MPF-01 PTD 95-045 10/25/95 N//[ ' N N ' 0 ~lever utilized - BPX MPU MPF-06 PTD 96-002 6/19~ N/A N -y N 2/28~7 1927 II~f..t~j.~wyd~.,la7171nMPF.14;valumefmi~&1998~~ BPX MPU' MPF-13 P'rD 98-027 10/31/95 NIA N Y . __ 12/14/98 -- 3234 From BPXA Annular l.nJection Data Ere'y Screen BPX .................. MPU MPF-14 PTD 95-212 3/26/96 N/A N Y Y 8/29/98 18717 From BPXA Annular Injection Data En_~ Screen BPX MPU MPF-21 SUN 96-135 5/17/97_.___. N N 0 Never utilized, no sundry filed BPX MPU MPF-22 PTD' 95.201 3/31/95 N/A N Y N 2/28/97 ..... 6~:x36' ~e~? ~ ~ F.2S~ F-2S & ~-~; B__PX IMPU MPF-25 -- PT.D 96-018 11/8/95 N/A .... N Y. __ N ~2/28/97 9897 from BPXA 1995 & 1996 oo~rectad summaries BPX ' ,MPU' MPF.30 PTD ~5.184 2/5/98 NIA N N ~ 0 Never ut~ized aPX IMPU MPF-37 - PTD 95.025 11/10/95 NIA __ __ N Y N 2/2~7 7032 from ePXA i9e5 & 1~ c°rrected summaries BPX MPU 'MPF-38 PTD 95.168 3/22/96 NIA N Y N 2/28/97 ~232 1003~..bbl, lnt~ F-48 from..F-38; volume fi'om BPXA 1995 &1~6 corrected eammarte~ BPX ....MPU MPF-4~-'-'- ..... P-T-~'---- 95.058 ' 1/19/9~- 'N/A '~ N .Y .... 12/14/98 ' 17582,From BPXA Annular In. jectlon Data Entry Screen BPX MPU 'I~PF'-491 ~ SUN; 97.003 ._ 4115/97 ....... IN... [_N_ N 0 Never~.~ilized, no sundryfllad aPX faPU" MPF-53 _~_ PTD 95.108 2/18/96 ~I/A N Y 12/14/98 6051 From BPXA Annular !njectiOnData E~ntry Screen BPX MPU MPF'61 PTD 9,5-117 5/26/96 NIA N. Y 12/14/98 _ 5732 From BPXA Annular InJ~'tiort Data Ent~j Screen BPX MPU MPF-62 PTO 95'161 11/11/95 N/A N ~7 .... 'y- ......... 9/23/96 38~] ~-rom BPXA Annular Injection Date En~;y Screen BP~- ' MPU MPF-66 SUN 96-t42 9/20/96_ ...... Y N 0 Never utilized, no sundry filed ~Px '" MPU - MP15-89 PTD _ 95-125 5/23/96 N/A __. N .Y.. ........ _.12/14/98 9740 From t~PXA Annular Injection Dat__~a~Entry S(~een BpX MPU MPF-70 PTD 95.153 314/96' NIA N Y Y 2/28/97 19775 from BPXA 1995 & 1996 corrected summaries BPX MPU MPF-78 PTD '~5--'~144 7/10/96 NtA N Y Y 2/26/9~ 847e f~om aPXA t"~95 & t99e corrected summaries '" BPx "~IPU MPH--~----~'"--~..i PTD .... i 9~--2~-~8-~ ~T24"~-~---- NIA .............. N --- Y 12/14~ 8283 Fmm'BpXA ~,nnular' injection Da~ Entry Screen BPX MPU MPH-06 PTD 95.t 15 4/23/96 NIA N Y N 2/28/97 8515 from BPXA 1995 & ~996 corrected summaries aPX ~ I~PU- MPH.07 SUN §~?142--' 1/30/97 .... N N 0 _N_ev.~a.~n. osu_._~._~_~filed BPX MPU MPI-07 PTD ___ 9_5.151~ 10/8/96 NIA N Y Y 6/30~- 1680 From BPXA A~nn,~lar Injection _l::~a~_.Ent~y Screen; fmr~ MPI-07, MPI-051, BPX MPU MPJ-13 PTD 94:126... 2/19/96 NIA .................... N Y ¥. ....... ~_7' 14127 From BPXAAwnular Injection Data ~n_~. Soreen; from MPJ-13, MPJ-19__MPJ-.___16 BPX _____MPU. MPJ-18 PTD 95-169 1/4/96 . ~ N/A ........ .N__. _ Y ~__ _ ~2/26/97 __~985 from BPXA 1995 & t996 corrected summaries BPX .._MPU MPJ-19 PT___D.. 95-159 10/27/97 NIA ......... N___ N __0 Neve~ utilized BPX MPU MPK-02_~ SUN 96.081 8/7/96 N N 0 Never utilized, no sundry filed 'BPX _.Mp.U... MPK-05 SUN ~ 96-068 8111/95 ............................ Y____ N 0 Nave, utilized nos.,_qg.[~_s~_s~flled BPX MPU MPK-06 SUN 98.191 11!4~_7 N N 0 Never utttized~_n_~ su..__n_d fi_??~._~__ ...... BPX MPU MPK-09 PTD 96.067 NIA ....... was I~is wettdrtlled? BPX MPO - MPK-10 . P'J':~3 '~ ~'6-048'" NIA ~ Don't know tf drilled, needed amendment to AIO #10 BPX MPU MPK-17 -- PTD 96.028 12/15/96 NIA N Y Y 3/5/97 19608 aPX MPU , MPK-18 SUN 97.00~4 _ 2/1__.7/97~ ................... N ........ _N .... ..N_ ................. _0 Never utilize___d n__o s__und~r~ filed BPX iMP~ MPK-21i SUN___ 96-176 10/21/97 Y N 0 Never utllize~no sund__.~r~fllad BPX MPU MPK-25 SUN 96-032 3/24~96 N N 0Never utilized~~l_aflon,~ended we!l_~ BPX MPU MPK-30 ..... SUN 9__6.-168 11/26/96 ....... ¥ ...... _N_ ...................................... .0..,N__ever ~llzed,_._no~to__q.p_Job BPx -' ~PU MPK-33 ........ SUN 96.202 2/11/97 N ~. 9 ..N_everu_~tll[e_~dnos__q__s.u_~lryflled ~IPX -IMPU MPK-34 _ SUN 96.t69 11/25/97 N N _ .0_~_N_ever utllized~.n.o sund_ ~ed~__ _BPX _ !M~U~ .. MPK-38. ..... SUN __96-030. 6/2./~_.____~ ..................... N _ _N. ............... 4/1_1~__7 ....... 0_l.N__ev_er ulHiz~val BPX___. MPU~__ MPK-54 __ S__UN__ 96-!92 4f6/97 i¥ N. .......................... .0.~ ~ever utl_~zeU no sund~ filed BPX MPU MPL-16 PTD 95-080 11/24/9~'---' ~IA .N_ N 0 Never utilized ~PX MPU MPL-21 PTD 95-191 5/16/96 N/A tN__ ....... ~ ............ I ............................ p_ Never utilized BPX -' MPU MPL-24 PTD 9-~-070 6/4/95 --~ N/A N Y _.~ 12114/98 6790 From BPXA Annular Inj.ection Data Entr~ Screen ~ .. F.X,L ,.~uk~ ...... S.u...,-7- ~°°io30--~ .............~.~ ~. ~ , ..~ ................................. P~e5 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I~~~, ~~+I~~ DATE: March 5 2008 P. I. Supervisor FROM: Chuck Scheve, SUBJECT: No Flow Petroleum Inspector Trading Bay Unit King Salmon Platform K-26RD PTD# 1950830 Wednesday, March 5, 2008: I traveled to Chevron's King Salmon Platform and witnessed a no-flow test on well K-26RD. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was then shut in and observed for three hours with a minor pressure build up (<5psi) noted, when reopened the pressure dissipated rapidly with no sustained flow of gas or liquids. I recommend Well K-26 RD on the King Salmon Platform be approved continued no flow status. SUMMARY: Well K-26RD meets the AOGCC requirements for no flow status. N APR ~. ~ 2408 ALASKA OIL AND GAS CONSERVA~ION CO~IISSION ! I i 1 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May15,2003 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well K-26RD PTD 195-083 2003 Dear Mr. Johnson: On May 8, 2003, our Inspector Lou Grimaldi witnessed a "no-flow test" on Unocal's King Salmon Platform. Well K-26RD was tested. Mr. Grimaldi arrived on King Salmon Platform and found the well isolated from the production system and "flowing" to the girder tank at less than 1 psi, with a gas rate below the meter threshold of 180 scl/hr and making no fluid. Over the course of 3 hours, the well was shut-in, allowed to build up, then opened to flow 3 times. On each occasion, the initial gas rate of 900 to more than 1800 scl/hr blew down in about 2 minutes. At the conclusion of the final cycle, the well was confirmed to not be flowing using a "bubble bucket". It has been concluded that TBU well K-26RD (195-083) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any mason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board King Salmon. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL( 08/01/01 RECEIVED AUG 0 1 ZOO1 Alaska 0il & Gas Cons. Commissi0r~ Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform Approved and Proposed Annulus Disposal Wells Well K-6RD (Approved) Well K-12RD Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the AOGCC to dispose of drilling waste from proposed drilling on the Monopod platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you. Two wells, K-6RD and K-19, were approved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1RD, K-13RD2, K-18RD and will be used for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workovers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exceeding the 35,000 bbl limit on any one annulus. TherefOre, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King.doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings. Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long term storage of cuttings in drums. The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as they are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The Monopod-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mud cuttings from the Monopod platform to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. ~mson~/~' cerely, ~ Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager February 14, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Sundry Application (Form 10-403) McArthur River Field, King Salmon Platform, Well K-6RD Well K-12RD Well K-25 Well K-26RD ApplicatiOns for Annulus Injection Commissioner Heusser: Enclosed are Sundry Applications (Form 10-403) for King Salmon Well #K-6RD, K-12RD, K- 25 and K-26RD. Unocal requests permission to dispose of oil-based mud and cuttings from the upcoming drilling program at King Salmon into the 9-5/8" x 13-3/8" annulus at these four wells in addition to the annulus of K-19 which had a Sundry Application Form 10-403 submitted 12/28/00. The planned drilling program at King Salmon will be K-1RD2, K-13RD2, K-5RD, K-20RD and potentially K-18RD. There are five proposed annuli because if one of the annuluses becomes plugged during disposal operations, the process can continue in the remaining four annuli. The attached pages to each Sundry Application provide information required under 20 AAC 25.080 regarding annulus disposal. Also included for all four applications is a summary of all the surface casing cement jobs at King Salmon and a summary of leak-off tests performed beneath the surface casing. There has been no prior annulus disposal at any of the wells at King Salmon platform according to ARCO and Unocal records and production personnel on the platform are not aware of any prior annulus disposal at King Salmon. The expected start date for annulus disposal is March 1, 2001 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager F ECEtVED FF_ 5 001 Alaska Oil & Gas Cons. Commission Anchorage AOGCC cover letter K-25.doc Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter s. uspended well: Alter casing: Repair well: Plugging: Time extensi(~n: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular Injection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or .KB) Union Oil Company of California (UNOCAL) Development: X 100' KB abov~/l~L feet 3. Address Exploratory: 7. Unit or Property/ame P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading B,,a'y Unit 4. Location of well at surface ~ 8. Well nu/Ff~er 725' FSL & 133' FEL of Sec. 17, T9N, R13W, SM ~ ~ F=~ ~\ ,¢~ ~ King{Salmon K-26RD At top of productive interval ~;' ~ ~ ~ ~ v~ ~' L~ 9. Pe~it number 4393' FSL &2236' FEL of Sec 17, T9N, R13W, SM j~ /95-83 At effective depth ~'1~ I 5 ?NN1 .,,,,,1,~.APInumber 3 ~ L~ -~ ~. u u ~ [j~,/ 50- 733-20097-04 At total depth ......... \,, _~_/ 11. Field/Pool AlaSKa Ull ~x uts t.,0Rs omm ~, 4435' FSL & 268' FEL of Sec 17, TgN, R13W, SM ' ~ ..ib ..... ~ L~t %1~/? McArthur River/Hemlock & G zone Pool 12. Present well condition summary Total depth: measured 11,078 feet Plugs (measured)~ true vertical 9,967 feet Effective depth: measured 10,933 feet Junk (rr~aCred) None true vertical 9,823 fe,e~,t Casing Length Size Obm'ented Measured depth True vertical depth Structural // _ Conductor 350' 24" i~\,,j ~ Circ to Surf ~ 350' 350' Surface 2938' 13-3/8~ /~ /2050 sx circ to surf 2938' 2710' Intermediate 8672' 9~.~~,~ / 481 bbl 8672' 7706' Production ~ ~'~ ~ Liner 2632' ~ 7"/ ~j/ 230_ bbl _ 8399'-11031' 7479'-9926' Perforation depth: measu red 101 ~,10368'- 10410', 10420'- 10440', 10482'- 10512', 10535'- 10580', 10503'- 107_02 ,'~!/~ 18'-10774' true ve~cal 8998'-9666' / Tubing (size, grade, and measured depth)//3'1/2" 9.3#, L-80 @_10239' Packers and SSSV (type and measured depth) ~ Baker FB-1 packer @ 10,000'- /' 3-1/2' Baker TE-5 SSSV @ 315' 13. Attachments Description suture? of proposal: x Detailed operations program: BOP sketch: / 14. Estimated date for commencing operation/ 15. Status of well classification as: 3/1/00 / 16. If proposal well verbally approved: / Oil: X Gas: Suspended: / Name of approver )/ Date approved Service: 17. I here, b~certify thallCh@~foregoing~'s true and correct to the best of my knowledge. Signe~t~!~~~D~n Williamson(~)~ J) )11' I"~'~A Title: Drilling Manager Date'~ ' ' / FOR COMMISSION USEONLY Conditions of approval: Notify ~lommission so representative may witness ' IApproval No. Plug integdty___/L. BOP Test Location clearance Mechanical Int/e(jdty Test Subsequent form required 10- / Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL ) RKB to TBG Hanger = 32.85' 2,3 PBTD = 10933' TI) = 11078' MAX HOLE ANGLE = 34° K26schACT.doc SIZE WT Trading Bay Unit King Salmon Platform Well # K-26RD Current Completion 5/28/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 24" 13-3/8" 68 9-5/8" 53.5 7" 29 Tubing: 3-1/2" 9.3 3-1/2" 9.3 surf 350' K-55 BTC surf 2938' P- 110 BTC surf 8672' L-80 BTC 8399' 11031' L-80 TDS surf 10000' L-80 Butt 10000' 10239' NO. Depth Item 1. 315' 2. 9998' 3. 10000' 4. 10176' 5. 10239' JEWELRY DETAIL 4-1/2" butt btm hanger with 3-1/2" TDS Xover Baker TE-5 SSSV (ID = 2.810") Baker locater with 10' seal assy Baker 7" FB-1 packer (4.000" ID), MOE 4.50" Baker 3-1/2" XN nipple (ID=2.650") Baker shear out sub Gas Lift Information 1 2383' 3-1/2" Camco MMM mandrel 2 4137' 3-1/2" Camco MMM mandrel 3 5294' 3-1/2" Camco MMM mandrel 4 6337' 3-1/2" Camco MMM mandrel 5 6849' 3-1/2" Camco MMM mandrel 6 7361' 3-1/2" Camco MMM mandrel 7 7871' 3-1/2" Camco MMM mandrel 8 8443' 3-1/2" Camco MMM mandrel 9 9047' 3-1/2" Camco MMM mandrel 10 9590' 3-1/2" Camco MMM mandrel PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 10105 10195 G5 10300 10328 10368 10410 10420 10440 10482 10512 10535 10580 10603 10702 10718 10774 HB1 HB2 HB4 HB4 HB4 1-134,5,6 HB6 FEB 1 5 2001 Alaska Oil & Gas Cons. Commission Anchora9e REVISED: 01/25/01 DRAWN BY: TAB Information Required for Annulus Disposal of Drilling Waste 20 AAC 25.080 K-26RD Annulus to be used for disposal: K-26RD, 9-5/8" x 13-3/8" annulus, 13-3/8" shoe is at 2938' MD/2710' TVD. Depth to the base of freshwater aquifers and permafrost There is no permafrost at the King Salmon platform. At the 13-3/8" casing shoe depth of 2938' MD/2710' TVD for K-26RD, the formation waters exceed 6000 ppm chlorides. Also, there is a fresh water exemption for wells at the King Salmon platform. Stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or, except to the extent allowed under (e) .1 of this section, contaminate freshwater The 13-3/8" shoe is at 2938' MD/2710' TVD in K-26RD. This corresponds to the Middle Tyonek formation. The waste is expected to be confined within this strata as this is the primary gas trap in the McArthur River Field with no evidence of surface breaching. 4 List of all publicly recorded wells within ~A mile, and all publicly recorded water wells within one mile, of the well that will be receiving drilling waste The attached plat shows the adjacent wells to King Salmon K-26RD. 5 Types and maximum volume of waste to be disposed of and the estimated density of the waste slurry The waste will consist of 9.0 ppg oil base mud with small concentrations of drill cuttings mixed with high concentrations of water or ground cuttings slurrified in gelled water. Seawater will be injected ahead and behind the waste slurry injections. The average density of the waste will be appx. 8.8 ppg when the seawater dilution and the pre/post- flushes are taken into account. The estimated maximum volume from the five potential redrills to be disposed of is 8,000 bbls OBM/water and 26,000 bbls seawater. Description of any waste souqht to be determined as drilling waste under (h)(3) of this section: 20 AAC 25.080(h)(3) Other substances that the commission determines upon application are wastes associated with the act of drilling a well permitted under 20 AAC 25.005. None at this time. 7 Estimate of the maximum anticipated pressure at the outer casing shoe during disposal operations and calculations showing how this value was determined. An injectivity test was performed on the 9-5/8" x 13-3/8" annulus of K-26RD on 10/26/00 and 700 BWPD was injected at 1900 psi. The maximum injection pressure while disposing of mud and cuttings down the K-26RD annulus will be 2000 psi. The proposed AOGCC ann disp info K-26RD.doc Tim Billingsley 2000 psi limit on injection pressure will not cause a problem with 13-3/8" casing burst or 9-5/8" casing collapse as shown in item #9. Details that show that the shoe of the outer casincj is set below the base of permafrost, if present, and any freshwater aquifer,other than freshwater excepted under (e)(1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include (A) cementinq records; and (B) a cement quality Io~ or formation inteqrity records; The 13-3/8" shoe on K-26RD was set at 2938' MD/2710' TVD which is below any freshwater aquifer. (A) The 13-3/8" casing was cemented on 12/20/93 with 1400 sx (474 bbls) of 13.2 ppg lead cement and 650 sx (133 bbls) of 15.8 ppg tail cement. Full returns were observed throughout the job 80 bbls of cement returns to surface. (B) No bond log was run on the 13-3/8" casing. There was a leak off test below the 13- 3/8" shoe performed on 12/23/93. The LOT was 13.8 ppg EMW. This is based on the 13-3/8" shoe depth of 2938' MD/2710' TVD and 8.6 ppg mud which was pumped away at 735 psi. Details that show that the inner and outer casinq strings have sufficient strenqth in collapse and burst to withstand the anticipated pressure of disposal operations: The 13-3/8" outer casing in K-26RD is 68#, K-55 which has a burst rating of 3450 psi for new pipe. Therefore, the anticipated maximum injection pressure of 2000 psi will not be a problem and will only be 58% of new pipe burst rating. The 9-5/8" inner casing in K-26RD is as follows: 53.5#, P-110 from surface to K-26RD window at 8672', collapse rating - 7930 psi The 7", 29#, L-80 liner in K-26RD is from 8399' to 11031' The collapse force exerted by the anticipated maximum injection pressure to 2000 psi on the 9-5/8" x 13-3/8" annulus would be: (2000 psi + (8.8 ppg x .052 x TVD)) minus the internal gas lift pressure on the 9-5/8" x tbg inner annulus which is 1020 psi. The worst case would be just above the top of the 7" liner at 8399' MD/7479' TVD in the 9-5/8" 53.5# P-110 which would be: ((2000 psi + (8.8 ppgx.052x7479'))-1020 psi =4402 psi- 56% of new collapse rating of 7930 psi for 9-5/8 53.5#, P-110 casing This collapse pressure is acceptable and there will be a requirement placed on the annulus disposal crews to verfiy that the K-26RD inner annulus does have 1020 psi in gas lift pressure before injecting in the outer 13-3/8" x 9-5/8" annulus. The injectivity test in K-26RD on 10/26/00 indicated the formation below 2938' MD/2710' TVD will readily take fluid at 1900 psi. 10 The downhole pressure obtained durinq a formation integrity test conducted below the outer casin~ shoe; Originally, K-26RD was named K-8. K-8 was drilled in 1968 by ARCO. There was no leak-off test performed when the 12-1/4" hole was drilled below the 13-3/8" casing shoe at 2571' MD. When the well was redrilled in 1993 by Unocal, the well was renamed K-26. The 9-5/8" casing was cut and pulled all the way back to surfaceand the 13-3/8" was cut and milled up. A new 13-3/8" surface casing string was run and cemented at 2938' MD/2710' TVD. On 12/23/93, a leak-off test was performed after drilling below the 13-3/8" shoe to 2946' MD/2716' TVD with 8.6 ppg mud. The pressure built to 735 psi before leaking off which equates to a 13.8 ppg EMW. There was no indication of any circulation to surface so this would indicate a frac gradient of .72 psi/ff. On 10/26/00, an injectivity test with 8.5 ppg filtered inlet water was performed down the 9- 5/8" x 13-3/8" annulus of K-26RD. The test injection rate was 700 BPD at 1900 psi. The 13-3/8" x 24" annulus was monitored during this test. There was no communication up to the 24" conductor set at 350' during the injectivity test. Due to the Iow frac gradient and the record of good 15.8 ppg tail cement around the 13-3/8" shoe, all of the injection was entering the formation below the 13-3/8" shoe and not migrating around and up the outside of the 13-3/8" casing shoe. As per 20 AAC 25.080(e)(2), Unocal requests the AOGCC to grant an exception for the downhole disposal pressure exceeding the downhole pressure obtained during the formation integrity test conducted below the outer casing shoe in 1993. The proposed maximum disposal pressure of 2000 psi at the surface with 8.8 ppg disposal slurry as opposed to the 750 psi with an 8.6 ppg mud during the leak off test in 1993 is justified due to the good 15.8 ppg tail slurry pumped at the 13-3/8" casing shoe with cement circulated to surface, the evidence of no communication up to the 24" conductor shoe at 350' during the injectivity test, and the geological interpretation that the Middle Tyonek formation is sufficiently confined with no evidence of surface breaching in the McArthur River Field. 11 Identification of the hydrocarbon zones, if any, above the depth to which the inner casinq is cemented; The 13-3/8" shoe is at 2938' MD/2710' TVD and the 9-5/8" casing was run to 9359' and cemented on 1/8/94 on K-26. There was no bond log run on the 9-5/8" casing. The 9- 5/8" casing was cemented with 342 bbl of 12 ppg lead cement and 139 bbl of 15.8 ppg tail cement. The calculated top of cement was 3684' MD. This calculated TOC is based on the following: 342 + 139 - 481 bbl total cement pumped Float track = 80' x .0732 bbl/ft - 6 bbls Rathole = 9366-9359' = 7' x .0146 bbl/ft of 12-1/4" hole = 0 bbls Cement behind pipe - 481 - 6 = 475 bbls No caliper, annulus size -- .0558 bbl/ft for 12-1/4" hole by 9-5/8" csg Cmt behind pipe - 475 bbls/(.0558 x 1.5 for est 50% washout) = 5675' TOC= 9359' - 5675' = 3684' K-26 was redrill in 1995 as K-26RD with a window cut in the 9-5/8" casing at 8672' and a liner run from 11031' to 8399'. This does not affect the 9-5/8" TOC estimation above. The open annulus in K-26RD is therefore from 2938' MD/2710' TVD to 3684' MD/3353' TVD which is in the Middle Tyonek of the Northwest Feature of the McArthur River Field. This interval is Iow on structure and there are no hydrocarbon zones present. 12 The duration of the disposal operation, not to exceed 90 days; Unocal requests permission to use K-26RD's 9-5/8" x 13-3/8" annulus for oil based mud and cuttings disposal for more than 90 days. It is anticipated that the Workover/drilling program at King Salmon will be 3 workovers and up to 5 major redrills. The first drilling well will be K-1RD and disposal from this drilling well should commence about 3/1/01 and the entire drilling program could last until December 1,2001. Disposal operations for the drilling mud from the five drilling wells should be completed by December 31, 2001. There will be applications for annulus disposal at four other wells at King Salmon in case one or more annuli become plugged. The five wells which will be applied for annulus disposal are: K-6RD, K-12RD, K-19, K-25 and K-26RD. 13 Whether drillin_cl waste has previously been disposed of in the annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated; No drilling waste has previously been disposed of in the annular space of K-26RD. There has also been no known annulus disposal at any of the other King Salmon wells. 14 The well where the drillinq waste to be disposed of was or will be generated; The 2001 proposed drilling program consists of K-1RD, K-13 RD, K-20RD, K-5RD and possibly K-18RD. There will also be 3 workovers at K-15RD, K-24RD and K-30. Fluids from these three workovers will not be disposed of in the K-26RD annulus. 15 If the operator Drol~oses not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent; Compliance with section (d) limitations as outlined below will not be a problem. The commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well. (2) For a period longer than one year through the annular space of a single well (3) Into a hydrocarbon-bearing stratum; or (4) Through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. 16 Any additiOnal data required by the commission to confirm containment of drillina waste; The attached spider plot describes K-26RD's 13-3/8" casing shoe in relation to other King Salmon wells' 13-3/8" shoes. In order to verify that the proposed annulus injection in K- 26RD does not communicate to other wellbores, Unocal proposes to monitor the following four 9-5/8" x 13-3/8" annuli: K-6RD, K-12RD, K-22RD, and K-25. These four wellbores are close to K-26RD and in different directions from K-26RD thereby surrounding the proposed injection point with monitoring locations. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage King Salmon Platform Surface Casing Cement Summary Well Surf Csg Size Shoe MD Shoe TVD CmtV01ume, sx Comments K-1 RD 13-3/8" 2384' 2147' 2608+80 Tag firm cmt at 82', pump 80 sx top job with cmt to surf K-2RD 13-3/8" 2372' 2298' 2608+450 Lost returns during primary job, pump 450 sx top job @ 350' with cmt to surf K-3RD 13-3/8" 2506' 2337' 1560 No top job required No cmt to surf on 3675 sx primary job. Top job found TOC @ 125', pump 125 sx with K-4RD 13-3/8" 2880' 2769' 3675+125 good cmt to surf K-5 13-3/8" 2476' 2252' 1625 Cmt returns to surf K-6RD 13-3/8" 2186' 2088' 1760 Cmt returns to surf K-7RD 13-3/8" 3618' 3039' . 1600 650 sx 1st stage and 950 sx thru DV tool @ 1480' K-9 13-3/8" 2492' 2360' 1625 = No top job required K-10RD 13-3/8" 4998' 3883' 2255 1300 sx 1st stage, 955 sx thru DVT @1511', 335 sx cmt returns to surf K-11 13-3/8" 2470' 2400' 1550 Cmt circ to surface, 500 cuft K-12RD 13-3/8" 2510' 2429' 1500 Cmt circ to surface, 150 sx. K-13RD 13-3/8" 5011' 4166' 1050+200 650 sx 1st stage, 400 sx thru DVT @ 2509', 200 sx top job @ 180' with 25 sx to surf K-15RD 13-3/8" 2401' 2284' 1550 Cmt circ to surf, 500 cuff K-17 13-3/8" 2183' 2032' 1371 Cmt circ to surf, 350 cuff K-18 13-3/8" 2477' 2283' 1800 Cmt circ to surf, 1030 cuff K-19 13-3/8" 2591' 2302' 1750 Cmt circ to surface, 800 cuff K-20 9-5/8" 4999' 2899' 2325 1400 sx 1 st stage, 925 sx thru DVT @ 1396', circ 150 sx cmt to surf on 2nd stage K-21 RD 13-3/8" 2714' 2390' 1775 Cmt circ to surface, 798 cuff K-22R D 13-3/8" 5493' 4825' 2200+500 1500 sx 1 st stage, 700 sx thru DVT @ 2881 ', 500 sx (905 cuff) bradenhead top job K-23 13-3/8" 5005' 3940' 2387 Cmt circ to surface K-24RD 13-3/8" 5712' 4229' 2412 Cmt circ to surface, 798 cuff K-25 13-3/8" 1997' 1997' 1260 Originally known as K-16, cmt circ to surface K-26RD 13-3/8" 2938' 2710' 2050 Cmt circ to surface, 80 bbls. K-30RD 13-3/8" 2187' 2012' 1490 Cmt circ to surface Bold indicates updated information from K-19 12/28100 info and 1/23/01 info. o 1/26/01 Tim Billingsley KS surf csg cmt and LOTsummary.xis King Salmon Platform Surface Casing Leak-off Test Summary Well Surf Csg Size Shoe MD Shoe TVD LOT, ppg Comments K-1 RD 13-3/8" 2384' 2147' No leak-off test performed below 13-3/8" shoe, 11/2/67 K-2RD 13-3/8" 2372' 2298' No leak-off test performed below 13-3/8" shoe, 11/10/67 K-3RD 13-3/8" 2506' 2337' No leak-off test performed below 13-3/8" shoe, 10/68 K-4RD 13-3/8" 2880' 2769' No leak-off test performed below 13-3/8" shoe, 1/15/68 K-5 13-3/8" 2476' 2252' No leak-off test performed below 13-3/8" shoe, 2/26/68 No leak-off test performed below 13-318" shoe, 2/26168, on original K-6 well. K-6RD had 9-5/8" cut and pulled and an open hole kick-off; LOT on 4110/88 @ K-6RD 13-3/8" 2186' 2088' 15.0 2295' MDI2190' TVD was 15.0 ppq EMW, K-7RD 13-3/8" 3618' 3039' No leak-off test performed below 1'3-3/8" shoe, 7/9/68 K-9 13-3/8" 2492' 2360' No leak-off test performed below 13-3/8" shoe, 5/28/68 K-10RD 13-3/8" 4998' 3883' :No leak-off test performed below 13-3/8" shoe, 1/24/69 K-11 13-3/8" 2470' 2400' No leak-off test performed below 13-3/8" shoe, 10/3/68 No leak-off test performed below 13-3/8" shoe, 12/9168, on original K-12 well. K-12RD had 9-518" cut and pulled and open hole kick-off just below 13-3/8' shoe K-12RD 13-3/8" 2510' 2429' but no LOT on 8119/78. K-13RD 13-3/8" 5011' 4166' No leak-off test performed below 13-3/8" shoe, 12/6/68 .K-15RD 13-3/8" 2401' 2284' No leak-off test performed below 13-3/8" shoe, 2/18/69 K-17 13-3/8" 2183' 2032' 10.6 2/5/73, pumped into formation at 150 psi with 9.2 ppg mud @ 2257' MD/2091' TVD K-18 13-3/8" 2477' 2283' 10.3 6/4/73, pumped into formation at 125 psi with 9.3 ppg mud @ 2492' MD/2295' TVD K-19 13-3/8" 2591' 2302' 11.3 3/1/74, pumped into formation at 325 psi with 8.6 ppg mud @ 2637' .MD/2336' TVD K-20 9-5/8" 4999' 2899' No leak-off test performed below 9-5/8" shoe, 7/17/69 K-21 RD 13-3/8" 2714' 2390' No leak-off test performed below 13-3/8" shoe, 5/23/75 K-22RD 13-3/8" 5493' 4825' 11.3 2/17/75, pumped into formation at 550 psi with 9.1 ppg mud @ 5560' MD/4852' TVD K-23 13-3/8" 5005' 3940' 12.5 2/9/78, pumped into formation at 625 psi with 9.5 ppg mud @ 5070' MD/4000' TVD K-24RD 13-3/8" 5712' 4229' No leak-off test performed below 13-3/8" shoe, 10/28/79 Originally known as K-16, no LOT on 3/23/69. K-25 had 9-5/8" cut and pulled and an open hole kick-off: LOT on 6/26/85 @ 2202' K-25 13-3/8" 1997' 1997' 11.5 @ shoe MD/2202' TVD with 9.1 ppg mud pumped away @ 250 psi. 12/23193, pumped into formation @ 735 psi with 8.6 ppg mud @ 2946' MD/2716' K-26RD 13-3/8" 2938' 2710' 13.8 TVD K-30RD 13-3/8" 2187' 2012' No leak-off test performed below 13-3/8" shoe, 1/29/70 Bold indicates updated information from K-19 12/28/00 info and 1/23/01 info, RECEIVED Tim Billingsley FEB 1 5 2_001 KS surf csg cmt and LOTsummary.xlsLOTs Alaska Oil & Gas Cons. Commission Anchorage i/26/01 SCALE IN FEET RIYER ST. 2 Bay Unit Boundary ~ K-12RD !:ii K] K-IBC- K-10 K-10RD ~' K-1 W. FORELAN K-SRD K-19 ~ iI. K-~ 'i' G-15 G-a9RD G-13 G-27 30 e' G-19 G-5 I G-17 K-7 K-17 ]0 (OH) G-25 K-TRD K-2RD M-27 -25 G-Q~D K;-2 9 K-22RD J / / K-3 :ing%Prop Plats%King Prop OBMud Disp WelIs-K-'26RD.Dwg 1,000 2,000 SCALE% IN FEET \ \ 3~t~D 2284'(K-15RD) (K-Z?) 2400~ 3,000 M-30 K-6 K- 2 95 --- (,183 ,S C., ki P R E ,:'"..: C, R D 95 O 83 H U D 95 .... 083 95-083 PERF RECORD (.7.' C, L L 6E.,1 L O C /...~¢.. :8667 .-., i I (,)78 ~ ~C~'"' 10168 --- 10736 RCD 6 / 1 O/96~'~Y L,~.R 9910--10739 95 ~-- 0 8 ~ C C, Iq P 95-08~.} C. OkiP RCD 6/19J96t-~/HYL,~R 10000 .... 10773 i 95 .... 08..7, C,3, HP RCD/ENERJ_F'.{T d~klYLAR 10100---10500 O//1.~,~ .¢~ 'i 95---08:'S COkiP R,SD/ENERJET .'.-.i~ kiYLAR 10150-10/.i-50 OW ~.~6~ i 95 08{¢ PROD L.,S,G ~026(`1---t0750 i Da'Lc.: 06/0'2/9'? t-;~!JN /.SAFE ....RECVD i 0 .... ~ 0 '7 ..R-"SS O lq P L E l l O N D A T E '") / ti-/' ~'~ / Ar"e dr'y W a s 't.: h e A r" d,,. w e 'i i DAli..",' WELL dii:.ch sarnpies weii cor"ed ? · t e s 't s ops m"-o~v'O¢/'-~..F/' TO ?//{ /'q/Y r'equ~r'ed? yes ~ And r'ecei'ved? yes ~,~ y e s A n a l i/:: i ss & d e s c r" 'i p 't i' o i"~ r'equ'~red? yes ~ Received? yes ._./q i3 Unocal Oil & Gas 909 West 9th Ave. Anchorage, AK 99501 Tel: (907) 273-7889 Fax: (907) 263-7828 E-maih epardacl@anchorage, unocal, com UNOCAL Debra Childers Geoscience Clerk DATA TRANSMITTAL 96-32 October 16, 1996 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal SCU 321-9 Blueline / Film Completion Record 1 10/04/96 SCU 332-4 Blueline / Film Completion Record I 10/03/96 SCU 332-4 Blueline / Film Gamma Ray / CCL 1 10/03/96 TBU K-26 RD Blueline/Film Production Log I 9/29/96 TBU K-9 Blueline / Film Cement Retainer I 9/27/96 TBU K-9 Blueline / Film Depth Determination 1 9/28/96 · t,.,bz4 Unocal Oil & Gas 909 West 9th Ave. Anchorage, AK 99501 Tel'. (907) 273-7889 Fax: (907) 263-7828 E-mail: epardac l~anchorage.unocaL com UNOEAL Debra Childers Geoscience Clerk DATA TRANSMITTAL 96-26 August 29, 1996 L. Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal TBU M-2 Blueline / Film Completion Record 1 7/25/96 TBU M-2 Blueline / Film Gamma Ray / CCL 1 6/23/96 TBU M-2 Blueline / Film Completion Record 2 1/2 HSD 6SPF 2 8/04/96 TBU M-2S Blueline / Film Blueline / Film I 8/09/96 TBU M-2 Blueline / Film Cement Retainer 1 7/26/96 TBU M-2 Blueline / Film Bridge Plug I 7/26/96 TBU D-1 Blueline / Film Completion Record I 8/08/96 TBU D-40 .."~,~ Blueline / Film Completion Record 1 7/04/96 TBU D-43RD Blueline / Film Completion Record 1 7/03/96 TBU D-47 Blueline / Film Completion Record I 7/06/96 TBU K-26RD Blueline / Film Completion Record 1 8/01/96 TBU K-26RD Blueline/Film Completion Record 1 8/01/96 SCU 13-4 Blueline/Film Completion Record 1 7/26/96 MGS 17595-15RD Blueline / Film Ultrasonic Imager / GR 2 8/02/96 Cement Evaluation Log MGS 17595-15RD Blueline / Film Cement Bond Log I 8/02/96 MGS 17595-15RD Blueline / Film Ultrasonic Imager / GR 1 8/02/96 Corrosion Log -o~0 -Oil -, o%~' Please acknowledge receipt by signing and returning one copy of this transmittal or F~ to (907) 263-7828. I R~eiv~ by: J Date: .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-6247 Stratigraphic: Trading Bay Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 729' N & 133' W of SE Corner Sec. 17, T9N, R13W, SM K-26RD At top of productive interval 9. Permit number/approval number ~-~ ~ ~ ; - /. . 4393' N & 2236' W of SE Corner, Sec. 17, TgN, R13W, SM (9000' TVD) ~' '),.[-~ f ~' 95-83 At effective depth k...; . .. _ 10. APl number 50- 733-20097-04 At total depth 11. Field/Pool 4435' N & 2268' W of SE Comer Sec. 19, TgN, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 11,078' feet Plugs (measured) true vertical 9,967' feet Effective depth: measured 10,933' feet Junk (measured) Perf fun fish in tubing @ 9970' true vertical 9,823' feet TCP gun fish in casing @ 10774' Filled tagged 7/17/95 @ 10917' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 315' 24" Driven 350' Surface 2,904' 13-3/8" Yes 2,938' Intermediate 9,326' 9-5/8" Yes 9,359' ProductionRE'CEIVED Liner 2,632' 7" Yes 11,031' Perforation depth: measured see attached AUG I 3 1996 true vertical see attached Tubing (size, grade, and measured depth) Alaska Oil & Gas Cons. Commission 3-11Z', 9.2'/t, N-SO BTC @ 10,055' Anchorage Packers and SSSV (type and measured depth) Baker TE-5-SSSV @ 301', Baker FH packer @ 9,984' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. R..epresentative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/31/96 620 45 572 970 100 Subsequent to operation 8/6/96 683 143 646 1020 100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: : ; Signed: ,~¢~.._ ~f¢_.,4.,,~, Title: Date: ~-t.~. ~/~,[ Form 10-404 Rev 06/15~88 SUBMIT IN DUPLICATE K-26RD (Attch) ATTACHMENT #1 TBU WELL K-26RD PERFORATION INTERVALS I Existing Perforations: Bench G-5 10105'- 195' MD 8998'- 9088' TVD Bench H-4 10482'- 512 MD 9375'- 9405' TVD Bench H-5 10570'- 580' MD 9463'- 9473' TVD Bench H-4,5,& 6 10603' - 702' MD 9496' - 9593' TVD Bench H-5 & 6 10718' - 774' MD 9611' - 9666' TVD I New Perforations: Bench H-1 10300'- 328' MD 9193'- 9221' TVD 8/1/96 6HPF Bench H-2 10368'- 400' MD 9261'- 9293' TVD 8/4/96 6HPF Page 1 K-26RD (Attch) ATTACHMENT #1 TBU WELL K-26RD PERFORATION INTERVALS Existing Perforations: Bench G-5 10105'- 195' MD 8998'- 9088' TVD Bench H-4 10482'- 512 MD 9375'- 9405' TVD Bench H-5 10570' - 580' MD 9463'- 9473' TVD Bench H-4,5,& 6 10603'- 702' MD 9496' - 9593' TVD Bench H-5 & 6 10718'- 774' MD 9611'- 9666' TVD New Perforations: Bench H-.1 '10300'- 328' MD 9'193'- 922'1' TVD 8/'1/96 6HPF Bench H-2 '10368'- 400' MD 926'1'- 9293' TVD 814196 6HPF RECE vEF) ~aska 0il & Gas Cons, Commission Anchorage Page 1 Unocal Energy Resources Division 909 West 9th, P.O. BOX 19 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL( Debra Childers .... :" .. Clerk DATA TRANSMITTAL 96-15 July 9, 1996 To: Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. 7 Granite Point 22-13 RD ./blackline/film Completion Record, Run I 5/28/96 Granite Point AN-21 ~," blackline / filmCompletion Record, Run 1 6/04/96 Granite Point AN-39 RD.-'"' blacldine I film Completion Record, Run 1 5/30/96 MGS 17595'-31 ST2 ~' blackline / film Completion Record, Run 1 6/26/96 SCU 341-4 ~. blackline / film Completion Record, Run I 5/11/96 SCU 341-4 ... blackline / film Completion Record, Run 2 5/30/96 SCU 341-4 /'blackline / film TDT, Run 1 5/29/96 TBU G-26 ,/ blackline / film Completion Record, Run 1 5/30/96 TBU K-26 RD ,/ blackline / film Completion Record, Run 1 6/09/96 TBU K-26 RD ,..,-,blackline / filmCompletion Record, Run 1 6/19/96 TBU K-26 RD -/ blackline / film Completion Record, Run 2 6/28/96 TBU K-3 RD v/ blackline / film Completion Record, Run 1 6/21/96 TBU M-2 S v' blackline/film TDT, Run 1 6/23/96 TBU M-25 ~,/blackline / film Completion Record, Run 1 6/21/96.. TBU M-25 v' blackline / film Completion Record, Run 1 6/25/96 TBU M-25 ~ blackline / film Completion Record, Run 3 6/27/96 TBU M-5 ,/" blackline / film TDT, Run I 6/22/96 t ) ' Please acknowledge receipt by signing and retuming one copy of ~is transmittal or FAX to I Received by: Date: / tJUL ' ' Unocal Energy .Resources 909 West 9!h, P.O. BOX 196,.-,f Anchorage, AK 99519-6247 Teie~hone (90.9) 276-7600 F~tx (oW-z~- ?qR-7,q9~ Debra Childers Clerk DATA TRANS AiTYAL 96-i3 IHoward Oakland 1300! Porcupine ~ Q,m.. i ,.,,.,9 W. O'~h,.~,,, Avenue June 6,1996 ,Anchorage, AK 99501 i Anchoraae. AK 99519-6247 hAlaska Oil & Gas !Unocal Transmitting the following items. Granite Point / Anna-21 Granite Point / Anna-26 Granite Point / Anna-36 Granite Point / 42-23 RD Tradina ~ Trading Trading Bay Unit K-26 RD Bay Unit M-5 Bay Unit M-25 Trading Bay Unit M-25 Trading Bay Unit G-21 Trading Bay Unit G-21 Trading Bay Unit G-21 Trading Bay Unit G-21 Tradine ~v Unit G-21 I file'(/blackline -" Mm / blackline ~ .~mJ/blackline.- , blackline."" film ,,O"black!in e," ¢i¢'m / blackline,-- ¢ittn I blackline,-- ~fi' / blackline~ t¢~m'"/~.b I a c kli n e,--- f~'¢'/blacktine-- · .flfr:n / blackline.-" I.,~ / blacklineu- / blackline~ ,4rrm / blacklin '~i~/b,ack!ics-/ Unit ~' ~' Unit G-21 ~ / blackline,-- Unit G-21 ,.fir"rp I blackline,-' ¢ff'm / blackline ,- F Completion Record Tubing Packer Setting Record Completion' Record Perforating Depth Control Main Pass (Collar Locator) · Completion Record -Completion Record ~3ompletion Record CCL/Gamma Ray Cement Retainer 4/01/96 4~20~96 5/20/96 2/17/96 3/23/96 2/14/96 '4/24/96 4/30/96 4/03/96 4/08/96 Completion Record 4/13/96 Completion Record Completion Record Completion Record Gamma Ray/Temperature Tubing Cutter 4/18/96 4/22/96 4~25~96 4/I 5/96 4/1 O/96 4/08/96 Completion Record 5/17/96 RECEIVED P::z3.t-.e :.cknowiedge r~Ceipt by§igning and~retuming one copy of this transmittal or FAX to (907) 263-7828. dUN 11 Rec~.ix.'cd by: Date: Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL ) G. Russell Schmidt Drilling Manager Tuesday, March 26, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell' KING SALMON WELL K-26RD Attached, please find form 10-404 detailing the recent coil tubing operations on the subject well. If you have any questions, please contact the undersigned at 263-7676 or Dan Williamson at 263-7677. Sincerely,- A ~~ G. Russell Schmidt Drilling Manager GRS/leg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-6247 Stratigraphic: Trading Bay Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 729' N & 133' W of SE Corner Sec. t7, T9N, R13W, SM K-26RD At top of productive interval0 II INAL 9. Permit number/approval number 4393' N & 2236' W of SE Corner, Sec. 17, T9N, R13W, SM (9000' TVD) 95-83 At effective depth 10. APl number 50- 733-20097-04 At total depth 11. Field/Pool 4435' N & 2268' W of SE Corner Sec. 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 11,078' feet Plugs (measured) true vertical 9,967' feet Effective depth: measured 10,933' feet Junk (measured) PeR fun fish in tubing @ 9970' true vertical 9,823' feet TCP gun fish in casing @ 10774' Filled tagged 7/17/95 @ 10917' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 315' 24" Driven 350' Surface 2,904' 13-3/8" Yes 2,938' Intermediate 9,326' 9-5/8" Yes 9,359' Production Liner 2,632' 7" Yes 11,031' PeRoration depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.2/¢, N-80 BTC @ 10,055' Packers and SSSV (type and measured depth) Baker TE-5--SSSV @ 301', Baker FH packer @ 9,984' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/16/96 698 259 400 920 100 Subsequent to operation 3/12/96 455 193 487 1030 100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Servic~i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ',,, Title ~.~,tJ~- .-~Ik~.t~-Q~s(~'- Date: ;~ ~q c~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE K-26RD DAY 01 (3~06~96) R/U AND TEST BOPE. RAN 2.8" WASH OVER ASS'Y ON COILED TUBING W/WELL ON PRODUCTION. TAGGED FISH @ 9950' AND WASHOVER 9950' CTM TO 9956.5" CTM. NO PROGRESS; POH AND RECOVER 6" PIECE OF FISH. DAY 03 (3/08/96) COMPLETE RD ALL EQUIPMENT. DEMOB SAME TO SHORE. RETURN WELL TO PRODUCTION. WELL :. ~ STATE OF ALASKA , .- ALASF, IL AND GAS CONSERVATION COMfy' ION COMPLETIt , I OR RECOMPLETION Rr PORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS U SUSPENDED E~] ABANDONED{~ SERVICE D 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 95-83 3. Address -- ' - 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 ; 50-733-20097-04 9. Unit or Lease Name TRADING BAY UNIT 725' N & 133' W OF SE CORNER SEC.17, T9N, R13W, SM ~ ~. . At Top Producing Interval ~/~/~, ~. ~ ~ 10. Well Number 4393' N & 2236' W OF SE CORNER SEC.17, T9N, R13W, SM (9000%1;¥D) , K-26RD At Total Depth 11. Field and Pool 4435' N & 2268' W OF SE CORNER SEC.17, TgN, R13W, SM MCARTHUR RIVER/HEMLOCK 5. Elevation100, KBin feet (indicate KB, DF, etc.) 6. Lease DesignationADL 17594 and Serial No. 12. Date Spudded ,ll3'DateT'D'Reached ll4. Date Comp., Susp. orAband, ll5. Water Depth, ifoffshore ll6. No. of Completions 06/22/95 i 07/06/95 07/15/95 100' Feet MSL 1 17. Total Depth (MD +TVD)i 1078'/9967',i 18' Plug Back Depth (MD+TVD)10933'/9823' YEsl 9. Directional Surve~~ NO b.J 120' Depth where SSSv set30° feet MD J 21. Thickness of PermafrostN/A 22. Type Electric or Other Logs Run Schlumberger DIT- F/SDT- C/LDT- D/CNT- H/SCT- L/AMS-A 23. CASING, LINER AND CEMENTING RECORD I FT. i SETTING DEPTH MD I CASING SIZE I WT. PER GRADE TOP I BO-I-FOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 24" O' 350' DRIVEN NONE 13-3/8" O' 2938' 24" NONE 9-5/8" 52.5# L80 O' 9359' 17-1/2" NONE 7" 29# L80 8399' 11031' 8-1/2" NONE 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD TVD G5 10105'-10195' 8998'-9088' HE4 10603'-10619' 9895'-9511' HE5 10649'-10683' 9541'-9575' HE5,6 10720'- 10740' 9612'-9632' HE5,6 10740'-10774' 9632'-9666' 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD) 3-1/2", 9.2" 1,80 10045' 9990' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED None 27 PRODUCTION TEST Date First Production 7/28/95 Date of Test ! Hours Tested 9/17/95 Flow Tubing I Casing Pressure Press. 100 I 840 28. Method of Operation (Flowing, gas lift, etc.) ! Gas Lift PRODUCTION FOI~ OIL-BBL GAS-MCF WATER-EEL TEST PERIOD 1 CALCULATED' / OIL-BBL GAS-MCF WATER-EEL 24-HOURRATE I 1155 38 0 CORE DATA CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) 32.8 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. BHL corrected 2/19/96. RECEIVED FEB 21 1ff96 Form 10-407 rev. 7-1-80 Aia~a 0il & Gas Cons. Commission Andlor ~age CONTINUED ON REVERSE SIDE Submit in duplicate 29. 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. None 31. LIST OF A'I-FACHMENTS WELLBORE SCHEMATIC, DIRECTIONAL SURVEY 32. I hereby~cedify that the f~regoing is true and,~correct to the best of my knowledge Signed G. RUSSELL SCHMIDT Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where nototherwise 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 shouldshowthe 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". KING SALMON PLATFORM PRE-ACTIVATION K26RD DAY 1-3 (06/09/95- 06/11/95) MOBILIZE CREWS TO RIG. OFFLOAD EQUIPMENT FROM BOATS. INSTALL BOP'S AND HYDRIL. CHANGE OUT STABBING BOARD. RIG UP SERVICE LINES TO RIG. OFFLOAD EQUIPMENT AND SPOT CEMENT UNIT. R/U CEMENT UNIT. FILL ANNULUS WITH FIW. RIG UP TO TUBING. DAY 4 (06/12/95) COMPLETED BULLHEADING TWO TUBING VOLUMES BACK INTO FORMATION. R/U SLICKLINE AND RUN IN THE HOLE WITH 2.77" GAUGE RING. POOH WITH SLICKLINE. RIH AND OPEN SLIDING SLEEVE. POOH WITH SLICKLINE. CIRCULATE TUBING AND CASING ANNULUS. SHUT DOWN. MONITOR WELL. ZERO PRESSURES RECORDED. R/U SCHLUMBERGER AND SET BAKER TUBING PLUG AT 9981.5'WLM. POOH. RIH WITH TUBING CHEMICAL CUTTER AND CUT TUBING AT 9925'WLM. DAY 5 (06/13/95) R/D SCHLUMBERGER. INSTALL BPV. REMOVE X-MAS TREE. NIPPLE UP BOP'S. R/U FLOWLINES AND ACCUMULATOR LINES. REPAIR LEAKS TO ACCUMULATOR SYSTEM. TEST BOP'SWITH HALLIBURTON UNIT. P/U LANDING JOINT. DAY 6 (06/14/95) PULL BACK PRESSURE VALVE. INSTALL LANDING JOINT. UNSEAT HANGER CIRCULATE WELL CLEAN. R/U TO PULL TUBING. PULL 3- 1/2" TUBING COMPLETION TO SURFACE AND LAY DOWN SAME. M/U 6" BIT AND RUN IN THE HOLE PICKING UP 3-1/2" DRILLPIPE AND 5' DRILLPIPE. DAY 7 (06/15/95) CONTINUE PICKING UP AND RIH WITH 5" DRILLPIPE. R/U HALLIBURTON AND SPOT A 300 FT BALANCED CEMENT PLUG FROM 9,930' TO 9,630' MD-RT WITH 50 SX CLASS G PREMIUM CEMENT. PLUG IN PLACE AT 13.00 HRS. POOH AND REVERSE CIRCULATE AT 8694'MD-RT. NO CEMENT RETURNS DETECTED. POOH. P/U 6" BIT, 3 1/2" DP 9 5/8" CASING SCRAPER AND 8 1/2" STRING MILL. ASSEMBLY STOOD UP ON STRING MILL AT 171'MD- RT. POOH. REPAIR IRON ROUGHNECK. DAY 8 -10 (06/16/95 - 06/18/95) COMPLETE REPAIRS TO IRON ROUGHNECK. P/U 8 1/2" BIT AND RIH TO TOP OF LINER AT 9173'. (HAVING TO PUSH SIGNIFICANT AMOUNT OF SCALE / DEBRIS AHEAD OF BIT). CIRCULATE AT LINER TOP. POOH. RIH WITH TANDEM ASSEMBLY 6" BIT AND 9 5/8" CASING SCRAPER WITH STRING MILL. TAG TOC AT 9601'MD-RT. TEST CASING TO 3000 PSI FOR 10 MINS. POOH. RIH WITH BRIDGE PLUG ON E-LINE. COULD NOT PASS 7065'ELD. POOH. M/U 8 1/2" BIT, CASING SCRAPER ASSEMBLY AND RIH. TOOK WEIGHT AT 8443'MD~ RT. P/U KELLY AND WORK DOWN. POOH. R/U SCHLUMBERGER AND RIH WITH BRIDGE PLUG. COULD NOT PASS 6340'MD-RT. POOH. RIH WITH 8 1/2" BIT TO 8800'. POOH. RIH WITH SCHLUMBERGER CCL AND GR TO 6925'ELD. COULD NOT PASS 6925'ELD. POOH. RIH WITH SMALL OD TOOL (1 3/4" OD) GOT DOWN TO 9000'ELD. POOH. RIH WITH BRIDGE PLUG ON DRILLPIPE TO 6977'MD-RT. STRING STOOD UP. COULD NOT WORK DOWN OR UP. SET BRIDGE PLUG. POOH. P/U MILLING BHA. RIH TO TOP OF BRIDGE PLUG. START DISPLACING THE WELL TO MUD. DAY 11 (06/19/95) CONTINUE DISPLACING THE WELL TO MUD. START MILLING ON THE EZ-DRILL BRIDGE PLUG. RIH WITH TO 8800'MD-RT. CIRCULATE THE WELL CLEAN. POOH. P/U BRIDGE PLUG AND RIH ON DRILLPIPE TO 8712'MD-RT. R/U SCHLUMBERGER AND RIH WITH GR / CCL. PULL BRIDGE PLUG UP TO 8682'MD-RT. SET PACKER AT 8682'MD-RT. DAY 12 (06/20~95) R/D SCHLUMBERGER. POOH, SLIP AND CUT 100' DRILL LINE. CONTINUE POOH. CHANGE LOWER PIPE RAMS TO 5". PRESSURE TEST BOP'S TO UNOCAL SPECS. P/U WHIPSTOCK AND RIH. ORIENT MWD AND SET WHIPSTOCK AT 8662'MD-RT. MILL ON 9 5/8" CASING. CIRCULATE BOTTOMS UP AND POOH. DAY 13 (06/21/95) CONTINUE POOH AND LID STARTER MILL AND MWD. P/U WINDOW MILL AND WATERMELLON MILL AND RIH. MILL WINDOW IN 9 5/8" CASING FROM 8672' TO 8688'MD-RT. PUMP A HI-VIS PILL PRIOR TO POOH DAY 14 (06/22/95) CONTINUE POOH. P/U PDC BIT AND WATERMELLON MILLS AND RIH. REAM AND DRILL FROM 8665'MD-RT TO 8690'MD-RT. CIRCULATE BOTTOMS UP. POOH. LID PDC AND REAMING ASSEMBLY. P/U BIT, MOTOR AND MWD DRILLING ASSEMBLY. RIH. ORIENT MOTOR OUTSIDE WINDOW. DAY 15 - 17 (06/23/95 - 06/25/95) DRILL 8 1/2" HOLE FROM 8690' TO 9203'. CIRCULATE BOTTOMS UP PRIOR TO POOH TO SHOE FOR A SHORT TRIP. DRILL FROM 9203' TO 9484'. INCREASED TORQUE. CIRCULATE BOTTOMS UP. POOH TO CHANGE BIT. REAM LAST 90' OF HOLE TO TD. DRILL 8 1/2" HOLE FROM 9484' TO 9693'. DAY 18 (06/26/95) CONTINUE DRILLING 8 1/2" HOLE FROM 9693' TO 9727'. CIRCULATE BOTTOMS UP PRIOR TO POOH TO CHANGE ASSEMBLY. (UNABLE TO TURN TO THE RIGHT OR DROP AT REQUIRED RATE). ADJUST AKO MOTOR TO 1.2 DEGREES AND M/U NEW DIRECTIONAL ASSEMBLY. RIH AND REAM LAST 90 FT TO BOTTOM. DRILL ORIENTED FROM 9727' TO 9865'. DAY 19 (06/27/95) CONTINUE SLIDE DRILLING FROM 9,865' TO 10,000'. CIRCULATE BOTTOMS UP. POOH. L/D MUD MOTOR AND MWD. TEST BOP'S AND ALL RELATED EQUIPMENT. P/U BHA AND RIH. DAY 20 (06/28/95) REAM FROM 9,625' TO 10,000'. DRILL 8 1/2" HOLE FROM 10,000' TO 10,006'. REPAIR SWIVEL PACKING. DRILL 8 1/2" HOLE FROM 10,006' TO 10,093'. ATTEMPT TO MAKE A SURVEY. PIPE STUCK. ATTEMPT TO WORK PIPE FREE. JARS FIRED WHILE APPLYING TORQUE TO STRING, STRING BACKED OFF BELOW ROTARY TABLE. SCREWED INTO PIPE P/U 350K LBS. STRING BACKED OFF AT 420' BELOW ROTARY TABLE. RIH AND ENGAGED FISH. MADE UP AND TORQUED DRILLPIPE. CIRCULATE BOTTOMS UP. RIG UP FREE POINT TOOL. FREE POINT TOOL DID NOT PASS 9705'. ATEMPT TO PUMP TOOL DOWN WITHOUT SUCCESS. DAY 21 (06/29/95) POOH WITH FREE POINT TOOL. REDUCED OD OF TOOL AND RAN BACK IN THE HOLE. DID NOT PASS 9705'. POOH. ATTEMPTED TO RUN SPEAR AND SINKER BARS. DID NOT PASS 9705'. RIH WITH CCL AND SHOT ROD TO 10025'. POOH TO LOAD DETONATOR CORD. RIH AND BACKED OFF AT TOP OF STABILIZER ABOVE MWD TOOL. POOH WITH STRING SHOT. CIRCULATE HOLE CLEAN. POOH. LID BHA. FISH LEFT IN THE HOLE IS 44.8' LONG. P/U FISHING ASSEMBLY AND LID 13 JTS OF BENT HWDP. SLIP AND CUT 100' OF DRILLING LINE. RIH WITH FISHING ASSEMBLY CHECKING ALL CONNECTIONS FOP_:iVED FEB 2 A/aska Oil & Gas Cons. Commission DAY 22 - 24 (06~30~95 - 07~02~95) CONTINUE RIH WITH FISHING ASSEMBLY CHECKING ALL CONNECTIONS. REPAIR DYNOMATIC COOLING FAN. CONTINUE RIH WITH FISHING ASSEMBLY. CIRCULATE ABOVE FISH AT 10035' PRIOR TO SCREWING INTO FISH. SCREW INTO FISH, ESTABLISH CIRCULATION. START JARRING. JAR FISH FREE. CIRCULATE WELL CLEAN. POOH WITH FISH. RECOVERED ALL OF FISH. COAL DEPOSITS AROUND BIT AND NEAR BIT STABILIZER. LID FISH. P/U NEW BIT AND BHA AND RIH. START REAMING FROM 9,735' TO 10,093'. HIGH TORQUE EXPERIENCED CLEANING OUT HOLE FROM 10,087' TO 10,093'. DRILL 8 1/2" HOLE FROM 10,093' TO 10,461' ASSEMBLY TORQUING UP. CIRCULATE BOTTOMS UP. POOH TO CHANGE BIT. DAY 25 - 26 (07/03/95 -07/04/95) SLIP AND CUT 100' OF DRILL LINE. CHANGE OUT BIT AND RIH. REAM FROM 10,380' TO 10,461'. DRILL 8 1/2" HOLE FROM 10,461' TO 10,621'. ROTARY TABLE BROKE DOWN. WORK ON ELECTRICAL PROBLEM. FIX LOOSE WIRE ON ROTARY TABLE. DRILL 8 1/2" HOLE FROM 10,621' TO 10,922'. HIGH TORQUE NOTED. CIRCULATE BOTTOMS UP. DROP A SURVEY AND POOH FOR A NEW BIT. DAY 27 (07/05/95) CONTINUE POOH. RETRIEVE SURVEY (3.5 DEG). P/U NEW BIT. CARRY OUT BOP TEST. RIH AND WASH DOWN FROM 10,832' TO 10,922'. DRILL 8 1/2" HOLE FROM 10,922' TO 11067'. DAY 28 (07/06/95) CONT WORK ON RELOCATING AGITATORS ON RESV PITS. WORK CONT ON WEST RIG FLOOR ALONG W/PATCH-REPAIR HOLES IN UTIL ROOM WALLS. PAINT MlSC ITEMS & CLEAN AREAS AS REQ'D. i vI-;D FEB 21 1~6 A~ O~ & G~m Oon~. DAY 29 - 31 (07/07/95 - 07/09/95) CONTINUE RIH WITH CLEAN OUT ASSEMBLY. CARRY OUT A SHORT TRIP TO THE SHOE. RIH TO 11078' AND CIRCULATE AND CONDITION THE MUD. POOH LAYING DOWN HWDP, JARS, DC'S ETC. CHANGE TOP RAMS. M/U 7" LINER AND TIW LINER HANGER AND RIH. SHOE JOINT AT 11031'. UNABLE TO RECIPROCATE PIPE. GOOD CIRCULATION. CEMENT 7" LINER AS PER PROGRAM. PUMP 15 BBLS WATER SPACER FOLLOWED BY 40 BBL DUAL SPACER FOLLOWED BY 230 BBLS OF 15.8 PPG PREMIUM CEMENT SLURRY. DISPLACE WITH 235 BBLS. SET TIW LINER HANGER, PULL OFF SAME AND REVERSE CIRCULATE 1 STAND ABOVE THE LINER TOP. APPROXIMATELY 45 BBLS CEMENT RETURNS NOTED WHEN REVERSE CIRCULATING. POOH. LID TIW RUNNING TOOL. P/U CLEAN OUT BHA AND RIH. OVERBOARD LINE PLUGGED WITH CEMENT. CLEAN OUT SAME. CONTINUE RIH WITH CLEAN OUT ASSEMBLY. TAGGED CEMENT AT 8341' CLEANED OUT TO 8460'.(HARD CEMENT NOTED). RIH TO 10796'. DAY 32 (07/10/95) CONTINUED RIH. CLEANED OUT HARD CEMENT TO 10933'. CIRCULATE BOTTOMS UP. PRESSURE TEST CASING TO 3000 PSI FOR 10 MINS. TESTED GOOD. POOH L/D SCRAPER AND CROSSOVER. R/U SCHLUMBERGER AND RUN CET LOG FROM 10930' TO 8200'. POOH WITH SCHLUMBERGER. R/D SCHLUMBERGER. DUMP AND CLEAN PITS. RIH WITH 6" BIT AND 9 5/8" CASING SCRAPER. DAY 32 (07/11/95) CONTINUE RIH. TAG CEMENT WITH 9 5/8" CASING SCRAPER AT 8332' REAM DOWN THROUGH CEMENT WITH 9 5/8" CASING SCRAPER. CLEAN OUT MUD PITS. START LOADING FIW. START DISPLACING WELLBORE TO FIW CIRCULATE 1 1/2 VOLUMES OF FIW. PUMP 2 PPB CAUSTIC SWEEP FOLLOWED BY 200 BBLS FIW SWEEP. PUMP 100 BBLS "SAFE CLEAN" PILL FOLLOWED BY FIW. DISPLACED WELL TO 3% KCL FLUID. GAS LEAK IN PRODUCTION. SHUT IN WELL. POOH LID DRILLPIPE. DAY 33 (07/12/95) LID DRILLPIPE. SHUT DOWN TO REPAIR AIR SUPPLY REGULATOR. CONTINUE TO LAY DOWN DRILLPIPE. LAY DOWN DRILLPIPE FROM THE DERRICK. PULL WEAR BUSHING. RIG UP TO RUN COMPLETION. START RUNNING 3 112" SINGLE STRING COMPLETION. DAY 34 (07/13/95) CONTINUE TO RUN 3 1/2" COMPLETION STRING INSTALL SSSV, 11 GAS LIFT MANDRELS SLIDING SIDE DOOR, BAKER FHL PACKER, X NIPPLE AND GUN ASSEMBLY. (ALL ASSEMBLIES RUN WITH CROSSOVERS TO 3 1/2", 9.2 PPF, N80, TDS TUBING. R/U SCHLUMBERGER TO CORRELATE DEPTH OF PACKER. SPACE OUT COMPLETION STRING. LAND HANGER. R/U PTA AND RIH WITH PLUG FOR X NI'PPLE BELOW PACKER. DAY 35 (07/14/95) SET PLUG. R/U HALLIBURTON. TEST TUBING TO 500 PSI. SET PACKER WITH 1500 PSI AND TEST TUBING TO 2500 PSI. RETRIEVE X PLUG. INSTALL BPV AND NIPPLE DOWN BOP'S. NIPPLE DOWN RISER. UNOCAL KING SALMON PLatform K-26Rd slot #4-25 McArthur River Field TBU, Cook Inlet, ALaska ORiGiNAL SURVEY L [ ST [NG by Baker Hughes !NTEQ Your ref : EMS <8955 - 11078'· Our ref : svy4996 License : Date printed : 18-Jul-95 Date created : 26-Jun-95 Last revised : 10-Ju[-95 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 51 48.792,w151 36 18.403 SLot Location is n60 51 55.932,w151 36 21.085 SLot Grid coordinates are N 2511799.530, E 213764.943 Slot Local coordinates are 725.11N 132.82 W Reference North is True North FEB 2 1 UNOCAL KING SALMON Platform,K-26Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 1 Your ref : EMS <8955 - 11078'> Last revised : lO-Jul-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A Depth Degrees Degrees Depth C 0 0 R D I N A T E 0.00 0.00 0.00 0.00 0.00 N 0.00 100.00 0.11 54.01 100.00 0.06 N 0.08 200.00 0.19 334.47 200.00 0.26 N 0.08 300.00 0.46 47.34 300.00 0.68 N 0.31 400.00 0.97 90.15 39<2.99 0.95 N 1.45 450.00 1.92 174.57 449.98 0.12 N 1.95 492.00 0.75 104.00 491.97 0.65 S 2.28 554.00 1.50 195.00 553.96 1.53 S 2.47 613.00 2.50 223.00 612.92 3.22 S 1.39 675.00 4.75 232.00 674.80 5.79 S 1.55 765.00 8.25 249.00 764.21 10.40 S 10.52 855.00 11.00 267.00 852.96 13.16 S 25.13 981.00 12.70 292.50 976.35 8.49 S 49.95 107-/.00 13.70 304.80 1069.83 2.04 N 69.04 1172.00 14.10 319.90 1162.08 17.32 N 85.74 Dogleg Vert Deg/lOOFt Sect W 0.00 0.00 E 0.11 0.03 E 0.20 0.23 E 0.44 0.58 E 0.70 0.55 4.13 -0.39 4.32 -1.22 2.72 -2.12 2.32 -3.47 3.7'3 -5.19 4.40 -7.32 4.50 -6.21 4.33 4.73 3.10 19.84 3.83 38.92 1267.00 15.40 330.40 1253.96 37.14 N 9<2.42 1361.00 17.90 332.50 1344.02 60.81 N 112.26 1489.00 21.70 330.10 1464.43 98.79 N 133.15 1581.00 24.40 330.10 1549.08 130.01 N 151.10 1711.00 27.20 330.80 1~.11 179.24 N 178.9<2 1838.00 29.50 329.70 1777.87 231.58 N 208.93 1964.00 30.90 328.00 1~.77 285.80 N 241.73 2092.00 31.00 328.30 1996.54 341.72 N 276.46 2216.00 31.50 329.40 2102.55 396.7'/ N 309.74 2312.00 31.30 329.40 2104.49 439.82 N 335.20 3.12 61.61 2.74 87.79 3.04 129.88 2.93 164.69 2.17 219.45 1.86 277.76 1.30 338.63 0.14 401.63 0.61 463.42 0.21 511.59 2403.00 31.90 329.40 2262.00 480.87 N 359.47 2495.00 32.20 329.70 2339.98 522.95 N 304.21 2588.00 31.70 330.10 2418.89 565.53 N 408.89 2678.00 31.60 330.40 2495.50 606.53 N 432.32 2771.00 30.80 330.40 2575.05 648.42 N 456.12 0.66 557.52 0.37 604.58 0.58 652.09 0.21 697.76 0.(~5 744.38 2834.00 31.20 330.80 2629.05 676.69 N 472.05 28(>4.00 31.00 330.10 2654.74 690.17 N 479.69 3016.00 30.80 330.80 2785.16 758.07 N 518.19 3201.00 29.80 330.40 2944.89 839.39 N 564.00 3306.00 29.40 331.50 3105.75 919.27 N 608.38 3540.00 30.10 331.80 3239.45 986.52 N 644.~ 3725.00 31.70 331.80 3398.19 1070.24 N 689.56 3825.00 32.30 332.90 3482.9<2 1117.19 N 714.14 3941.00 32.80 332.90 3580.77 1172.75 N 742.58 4~5.00 33.40 333.20 3684.65 1233.11 N 77'3.26 0.71 775.81 1.38 79O.8O 0.27 8(~5.36 0.55 956.76 0.36 1045.40 0.46 1119.76 0.86 1212.25 0.04 1263.95 0.43 1324.98 0.50 1391.23 4189.00 34.30 333.40 3787.63 1294.81 N 804.30 W 0.73 4312.00 33.20 333.60 38439.90 1355.97 N 834.79 W 0.90 4434.00 32.30 333.20 39<22.50 1414.98 N 864.34 W 0.76 4558.00 31.30 333.20 4097.89 1473.30 N 893.80 W 0.81 4836.00 29.40 334.30 4337.78 159<2.26 N 955.96 W 0.71 i V E) FEB 2 1458'8~a.~,J~ (")il & Ga8 Cons. COEI.IJSSiOn 1525.82 ....... 1590.47 A~cho('age 1654.44 1792.18 49<21.00 27.90 333.60 4473.80 1~.03 N 988.58 W 0.9<2 1805.12 5148.00 27.60 333.20 4612.74 1731.39 N 1021.31 ~ 0.22 1936.73 5272.00 27.80 332.90 4722.53 1782.T7 N 1047.43 W 0.20 19<23.12 5427.00 28.00 332.50 4,559.52 1047.22 N 1080.70 W 0.18 2063.98 5611.00 28.20 331.80 5021.83 1923.85 N 1121.19 W 0.21 2148.48 ALL data is in feet unless otherwise stated Coordinates from slot #4-25 and TVD from wellhead (100.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 345.00 degrees. Declination is 0.00 degrees, Convergence is -1.40 degrees. Calculation uses the minintan curvature method. Presented by Baker Hughes INTEQ UNOCAL KING SALMON Ptatform,K-26Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref : EMS <8955 - 11078'> Last revised : 10-Ju[-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R DogLeg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 5828.00 28.70 331.80 5212.62 2014.95 N 1170.04 W 0.23 2249.12 6139.00 28.50 331.50 5485.67 2145.97 N 1240.75 W 0.08 2393.97 6447.00 29.10 331.50 5755.58 2276.37 N 1311.53 W 0.19 2538.25 6692.00 29.00 331.10 5969.75 2380.72 N 1368.66 W 0.09 2653.83 6938.00 29.10 331.10 6184.81 2485.30 N 1426.39 W 0.04 2769.79 7188.00 28.10 330.80 6404.30 2589.91 N 1484.49 W 0.40 7434.00 27.90 329.70 6621.50 2690.18 N 1541.80 W 0.22 2997.56 7557.00 27.20 329.70 6750.56 2759.30 N 1570.50 W 0.57 3052.43 7681.00 26.40 329.40 68z, 1.24 2787.50 N 1598.8~ W 0.65 3106.32 7805,00 26.10 329.00 6952.45 2834.60 N 1626.91 W 0.28 3159.09 7932.00 25.80 328.70 7066.64 2882.16 N 1655.66 W 0.26 3212.47 8028.00 25.80 328.30 7153.08 2917.79 N 1677.49 W 0.18 3252.54 8121.00 26.90 334.30 7236.43 2953.97 N 1697.25 W 3.10 3292.60 8216.00 28.60 339.60 7520.51 29<24.66 N 1714.50 W 3.15 3336.36 8312.00 29.30 345.20 7404.53 3038.92 N 1728.51 W 2.92 3382.74 8408.00 30.10 345.20 7487.92 3084.90 N 1740.66 W 0.83 3430.30 8504.00 31.20 345.50 7570.50 3132.25 N 1753.04 W 1.16 3479.24 8596,00 34.50 347.00 7647.78 3180.72 N 1764.87 W 3.69 3529.12 8688,00 36.49 347.28 7/22.68 3232.80 N 17-/6.75 W 2.17 3582.50 8955.00 35.6~ 328.41 7939.20 3376.94 N 18~5.15 W 4.16 3756.85 9048.00 34.16 322.32 8015.50 3420.70 N 1865.31 W 4.06 3786.92 9142.00 32.62 318.95 8093.98 3460.70 N 1898.08 W 2.56 38~4.04 9234.00 29.66 316.58 8172.72 3495.94 N 1930.02 W 3.48 3876.35 9329.00 27.29 316.29 8256.22 3528.76 N 1961.2~ W 2.50 3916.13 9423.00 24.39 314.38 8340.82 3557.92 N 19<20.00 W 3.21 3951.74 9517.00 22.35 314.89 8427.10 3584.11 N 2016.54 W 2.18 3983.90 9609.00 20.94 314.63 8512.61 3608.01 N 2040.63 W 1.54 4013.22 9704.00 18.42 312.72 8602.06 3630.12 N 2063.74 W 2.74 4040.56 9798.00 14.38 311.56 8692.21 3647.94 N 208~.40 W 4.31 4062.87 9892.00 7.75 311.48 8784.42 3659.90 N 2096.89 ~ 7.05 4077.91 9984,00 1.59 337.42 8876.07 3665.19 N 2102.04 W 6.91 4084.35 10076.00 1.33 357.48 8968.04 3667.44 N 2102.57 W 0.62 4086.66 10170.00 1.91 340.27 9062.00 3670.00 N 2103.15 W 0.80 4089.28 10261.00 2.37 334.05 9152.94 367'5.12 N 2104.49 W 0.56 4092.64 10355.00 3.14 330.78 9246.83 3677.12 N 2106.59 W 0.84 4097.05 10448.00 3.70 326.33 9339.67 3681.84 N 2109.50 W 0.66 4102.36 10541.00 3.89 320.10 9432.46 3686.75 N 2113.19 W 0.49 4108.06 10635.00 4.08 318.04 9526.24 3691.69 N 2117.47 W 0.25 4113.94 10728.00 4.46 316.85 9618.98 3696.78 N 2122.15 W 0.42 4120.07 10819.00 4.57 314.96 9709.70 3701.93 N 2127.14 W 0.20 4126.33 10912.00 5.03 312.41 9802.37 3707.30 N 2132.T7W 0.54 4132.97 11004.00 5.21 309.98 9894.00 3712.70 N 2138.95 W 0.31 4139.79 11035.00 5.28 309.42 9924.87 3714.51 N 2141.13 W 0.28 4142.10 11055.00 5.47 307.49 9944.78 3715.67 N 2142.60 W 1.31 4143.61 11078.00 5.47 307.49 9967.68 3717.01 N 2144.34 W 0.00 4145.35 Projected Data - NO SURVEY All data is in feet unless otherwise stated Coordinates from slot #4-25 and TVO from wellhead (100.00 Ft above mean sea level). Vertical sectioo is from wellhead on azimuth 345.00 degrees. Declination is 0.00 degrees, Convergence is -1.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 3 KING SALMON PLatform,K-26Rd Your ref : EMS <8955 - 11078'> McArthur River FieLd,TBU, Cook Inlet, Alaska Last revised : lO-Jul-95 Comments in weLLpath MD TVD Rectangular Coords. Co~nent 11078.00 9967.68 3717.01N 2144.34 W Projected Data - NO SURVEY Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOW 2935.00 2715.63 721.88N 497.80W 13 3/8" Casing 0.00 0.00 O.OON O.OOW 9359.00 8283.00 3538.50N 1970.64W 9 5/8" Casing 0.00 0.00 O.OON O.OOW 10956.00 9846.20 3709.89N 2135.671d 7" Casing AL[ data is in feet unless otherwise stated Coordinates from slot #4-25 and TVD from wellhead (100.00 Ft above mean sea Level). Bottom hole distance is 4291.19 on azimuth 330.02 degrees from wellhead. Vertical section is from wellhead on azimuth 345.00 degrees. Declination is 0.00 degrees, Convergence is -1.40 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ z0097-04 ,'dform ,,9 4, Conductor 25, K-26RD 'rrdn9 B(]y Unit McArthur River Field ~,, :,'B Elev. 100 FT. MSL TbqL..i ~n9 Depth 55.00 Ft. Mid-F~+: Deviation 35 Degs. )- 2938.0' 13,375" OD 12,515" ID 68.00t/ft K-55 ~RF CSG 29.~8.0 - 29;&0' SHOE 8399.0- 8399.0' HANGER .0-8667.0' 9.625" OD 8.681" ID 53.50t/ft P-110 PROD CS(; 8r:~.O - 8667.0' SHOE 31.7 - 33.0' ~;CR GLM ,, ,,~,mco MMO 5;09/- :~:,u.,~ ~I° ~'-,- ::VALVE ~"~[,~mco MMG GLM /3~,3.] - 57i.7 :,<v,", ~",,, C3mco MMG QLM 790!.7 - 77910/7:? VALVE i5, Comco MMG GLM 8442.2- 8450.8' ""- -:" '- .:-.__-~ '¢ALVr_ t4, Camco MM(;; GLM 9045.2 - 9052.0 :.:.-._.- 'ALVE ~;, Oamco MMG GLM 9609.8 9614.1 .,__ ,ALVE t2 Camco MM(; GLM KB ELL'V: I00' PBID: 109,33' Oil Well Perf'd 9/15/95 ,'laiform i ~.on(]u,,,,,ui K-i6RD -'-,:ding Bav Unit !:!>,~hur Riv'er Fled ..... RKB Elev, 100 r u...;.,,,J rt. Tbg,,,,,,i Fng Depth ~ '" "- Mid-Perf Peviafion 5,.! 31.]- 10010.1' 3.50" ol)2.992" ID 9.20t/P, loo~o,~ - ~0055,2' 2,~75" OD 2.~" 9891.5 - gSgl.b' dOINl' Radio Aclive Barker 992L7 - 9928.0' SLEgVE SSD 9972.0 - 9992.0' GUN FISH 9/1.5/95 Eneriet - ,. i,",:.ff ... 9999.1- ]0001.0' 2.81" ID BNDIN6 NIPPLE 10010,1 - 10010.g' 2,441" ID CRO%OVER 2 7/8" ~. Pin x 3 I/2" BIC. Box 10105.0 - 10195.0' PERFS 6-5, 7/17/95, 6HF,, 90', 4 5/8" TCP 6uns 10053.7 - 10055.2' JOIN] Auto ]bg. Release 10174..0 - 10917.0' GUN FISH T~ .A.ssy. 10917.0-10933.0' FILL 7/17/95 ~/2.20 Gr 10933.0-11078.0' CEMENT PLUG 1O98O.0-~0980.0' FLC~ I068b.0 - 10619.0' PERB HB-4, 8/1/95, 6HPF, !.4', 2 1/8" Enerjet Guns, 0 Phose 10649.0- 1068`].0' PERB HB-5, 8/1/95, 6HPF. z''' ,,, 2 1/8" Enerja Guns, 0 Phase 10720.0 - i0140.0' PERFS HB-5&6, 9/1`]/95, 6HPF., 20', 2 1/8" Enerjet Guns, gO Phase 10740.0 - 10774.0' PERFS NB-5&6, 7/28/95, 6HPf, ,]4', 2 1/8" [~jet I]uns, 0 Ph~ 10740.0- 10174.0' PERFS NB-5&6, 8/1/95, 6HF,. ~', 2 1/8" [nerjet Guns, 0 Phase oi Wet Perf'd 9/13/95 Unocal Energy Resources D~. 909 West 9th, P.O. BOX 196247 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOr. Debra Chiiders Clerk DATA TRANSMITTAL #26 September 7, 1995 To: Larry Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 VV. 9th Avenue Anchorage, AK 99519-6247 Unocal Granite Point 18742-28 RD2 Tape and Listin~ Trading Bay K-26RD Blueline / Sepia' Formation Mudlog ~ Trading Bay K-26RD 5' Blueline / SepiaPerforating Record ¢~ Trading Bay K-26RD I 5' Blueline/Sepia Completion Record / 2 1/8" Phased Retrievable Energet III Trading Bay K-211RDI 5' Blueline/Sepia Completion Record / 2 1/8' Energet III Please acknowledge ,recei~ signing an~retuming one copy of this transmittal or FAX to (907) 263-7828. MEMORAN[- TO: David John~Lt~, Chairma~ THRU: of Alaska Alaska Oil and Gas ~.,onservation Commission DATE: June 28, 1995 Blair Wondzell, P. I. Supervisor FROM: Jerry Herring, \~ SUBJECT: Petroleum Inspector FILE NO: aukkfl cd. doc BOPE Test, Pool Rig 58 Unocal, King Salmon Pit. McArthur River Field Well K-26, PTD #95-83 Tuesday, June 27 1994: i traveled to Unocai's King Salmon platform to witness a BOPE test on Pool Rig 58 completing a workover on well K-26. The BOPE Test Report is attached for reference. i found the rig to be in good condition. There were two minor failures - both the dart valve and the tubing hanger packing nut had small leaks which were repaired and retested good. The BOPE test took 2-1/2 hours. Paul Barr did a good job conducting the BOPE test. SUmmary: I witnessed the successful BOPE test on Pool Rig 58 completing a workover on Unocal's King Salmon platform. Attachment: AUKKF1CD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arc'dc Alaska Operator: UNOCAL Well Name: K-26 Casing Size: 9-5/8" Milled @ Test: Initial Weekly DATE: 6/27/95 Rig No. 58 PTD # 95-83 Rig Ph.# 776-6698 Rep.: Jim Harvey Rig Rep.: Paul Barr 8669' Location: Sec. 17 T. gN R. 13W Meridian SEWARD X Other MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD # OK Standing Orders Posted OK Well Sign OK Dri. Rig OK Hazard Sec. OK Test BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. t 250/5000 I 250/5000 P I 250/5000 P 1 250/5000 P 1 250/5000 P 2 250/5000 P n/a n/a n/a Pressure P/F 250/3500 P P MUD SYSTEM: Visual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP T~s't Quan. Pressure P/F I 250/5000 P f 250/5000 P I 250/5000 F/P f 250/5000 P CHOKE MANIFOLD: No. Valves 15 No. Flanges Manual Chokes Hydraulic Chokes 2 Test Pressure P/F 250 / 5000 P 38 250/5000 , P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,000 P 1,000 P 0 min~es 28 sec. 2 minu~s 59 sec. OK Remote: OK (4) BOTTLES 2400 Ave. Psig. Number of Failures 2 Test Time 2.50 Hours Number of valves tested 23 Repair o~' Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Dart Valve had minor leak, was fixed and retested good. Minor leak fixed on tubing hanger packing nut. The Permit To Drill needs to be posted. The rig was found to be in good condition. Paul Bart did a good job conducting the BOPE test. Distribution: orig-Weli File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GNEN YES X NO Waived By: Witnessed By: BOPTST1 .XLS AI~SKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: ADMINISTRATIVE APPROVAL NO. 80.70 The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill, complete and produce the TBU K-26RD well. Mr. Kevin Tabler Land Manager Alaska Business Unit · UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99519-6247 Dear Mr. Tabler: Your application of May 22, 1995 for a permit to drill the TBU K-26RD development oil well indicates that the drilling and completion of the well will provide additional oil recovery from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU K-26RD well pursuant to Rule 5 of Conservation Order No. 80. DONE at Anchorage, Alaska and dated June 16, 1995. Russell A. Douglass, Co sioner ' Tuckerman Babcock, Commissioner TONY KNOWLE$, GOVEBNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 16, 1995 G. Russell Schmidt Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99619-6247 Re: Trading Bay Unit K26RD UNOCAL Permit No. 95-83 Sur. Loc. 725'N, & 133'W of SE Cr, Sec. 17, T9N, R13W, SM Btmnhole Loc. 4797'N & 1985'W of SE Cr, Sec. 17, T9N, R13W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting David W. Johns~-6~-- ~ ~' ~- Chairman ~ ~ BY ORDER OF T~COMMI~ION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. --., STATE OF ALASKA ALASK,",~IL AND GAS CONSERVATION CO PERMIT TO DRILL IISSION la. Type of work Drill E] Re-Entn/r-1 20 AAC 25.005 Redrill ~ 1 lb. Type of well. Explorata7 ~ Stratigrsphic Test [-] Deepen r'l Servioe ["] DevelopmentC-,-,-,-,-,-,-,-,-~s ~ Single Zone [-] Development 011 ~ Multiple Zone r'l 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247~ Anchorage~ AK 99519 4. Location of well at sLrface Leg 4 Slot 25 725' N & 133' W of SE Corner, Sec. 17, 'igN, R13W, SM At top of productive interval 4555'N & 1933' W of SE Corner, Sec 17, T9N, R13W, SM At total depth 5. Datum Elevation (DF or KB) 100 i~3 feet 6. Property Designation ADL 17594 7. Unit or property name Trading Bay Unit 8. Well number K26RD 9. Approximate spud dam 10. field and Pool McArthLr Rivm'/I-lemlock 11. Type Bond iSlE a)ACC~O~ United Pacific Ins. Co, Number U62-926~ Amount 4797' N & 1985' W of SE Ccrner, Sec. 17, T9N, R13W, SM 6/15/95 12. Distance to nearest j41131 Distance to nearest well property line 480' feet (at surface) feet 5116 16. To be completed for deviated wells Kickoff depth 8700' feet Maximu'n hole angle 36.7' 18. Casing program size Specifications- Hole Casing Weight Grade Coupling Length 8-1/2' 7" 29L80 BTC 2528' 19. To be completed for Rectill, Re-entry, ancl Deepen Operations Present well condition summary Total depth: measured 10420' feet Plugs (measured) true vertical 9163' feet 14. Number of acres In property ,, 15. Proposed depth 11228' M D feet 17. Anticipated.Pressum~.. Maxlmum~urfm:~ 1200 pW~t~,~C'v~ 4600 ~ ,~ Setting Depth Top Bottom Quantity of cement MD 8700' 670 sxs ITVD ! MD TVD 773211228' I 10106' Effective depth: measured feet Junk (measured) true vertical feet (include stage data) P~ JUN -,5 1995 Uti & Gas C0ns. commission Casing Structcral Conductor Surface Intermediate Production Uner Length Size Cemented 350' 24" Driven 2938' 13-3/8" 2050 sxs 9359' 9-5/8" 2700 sxs 10,973' Perforation depth: measured 7' 550 sxs 10,148'- 10,372'; 10,564'- 10,814' Measured depth True vertical depth 350' 350' 2938' 2718' 9359' 8197' 10,973' 9668' true vertical 8,923'-9,238'; 9,295'-9,523' 20. Attachments Filing fee ~: Property plat r"l BOP Sketch~. - Dive.er Sketch B" Drilling program B Drilling fluid program ~: Time vs de~th plot ~ Refracti~on analysis I-1 Seabed report I'-] 20 APO 25.050 requiraments I-1 21.1 hereby certify that the foregoing ~¢ ancl,Tj~'?~.b~st_ of my knowledge Signed G. RUSSELL SCHMIDT~~./~'.-v~~ DRILUNG MANAGER Date 6/5/95 Commission Use Only Permit Number IAPI number lAp,ova! date ,~. ,.~' ISee cover letter ?5'- ~'.~ 15o-?..~3'" ~__.~:~o'~ -'~ I ~'/~ ~"'Y'"'~ Ifa'otherrequirements Conditions of approval Samples required F'I Yes ~ No Mud log requirecl I-] Yes ~ No Hydrogen sulfide measures ~ Yes I-'1 No Directional .s~Jrveyrequired ']~ Yes I-] No Requ~ed working p~e~u~efc~ ~OP~ 1-1 ~; El 3M; !~ SM; 1-1 ~OM;I-1~SM Other: Original $ignea By by the order of Approved by David W. Johnston Commissioner the commission Form 10-401 Rev. 12-1-85 Submi{ in t{iplicate Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL May 22, 1995 Kevin A. Tabler Land Manager Alaska Business Unit Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Trading Bay Unit State of Alaska Permit to Drill K-26rd Dear Mr. Johnston: Union Oil Company of California (Unocal), as Operator of the Trading Bay Unit, requests your approval to drill Trading Bay Unit K-26rd and further requests Administrative Approval, pursuant to Rule 5, for a spacing exception to Conservation Order No. 80. As part of this application, pursuant to 20AAC 25.105, we enclose in triplicate, an Application for Sundry Approval (form 10-403) to abandon the existing well K- 26. Additionally, in triplicate, is our application for Permit to Drill K-26rd (form 10-401) pursuant to 20 AAC 25.005 and our check No. 0100002912 in the amount of $100.00 as required under 20 AAC 25.005. (c)(1). Also enclosed, is Verification of Application by the undersigned stating that applicant is acquainted with the facts pursuant to 20 AAC 25.055 (b). Unocal intends to drill the K-26rd well from the King Salmon Platform into the Hemlock Oil Pool approximately 480' from the Unit boundary. Unocal and Marathon Oil Company are the Lessees of the lands adjoining the northern boundary of the Trading Bay Unit. K-26rd shall be completed at a crestal withdrawal point which will result in additional recovery of Hemlock Production. The specific location, interval and depth are as follows: 1. Surface Location: 725'FSL & 133'FEL, Section 17, T9N-R13W, SM. RECEIVED J U N - 5 1995 Alaska Uil & Gas Cons. Commission Anchor;,, 2. Top of Prod. Interval' 4555'FSL & 1933'FEL, Section 17, T9N-R13W, SM. 3. Total Depth: 4797'FSL & 1985'FEL, Section 17, T9N-R13W, SM. If you require addition information, please contact the undersigned at (907) 263- 7600 or Graham Brander, Drilling Dept. at 263-7671. We appreciate your review and trust that the enclosed is satisfactory. enclosures Very truly yours, / Kevin A Tabler RECEI /ED Gas Cons. Commission A~chors." FILL-UP KILL LINE ANNULAR BOP 135/~"3000 psi PIPE RAMS 135/8~5000 psi BLIND RAMS 135/~"5000 psi [T~L/J-IT~ ,,/[[- SPOOL ~/T1-]'~I/T] ~1~ 35/~5000 p~i~~ -~4" 5000 psi II I~ 4" 5000 I I PIPE RAMS FLOW --~:>- CHOKE psi LINE~-~> RISER ~3%" 5000 psi RECEIVED JUN - 5 1995 A!~ska 0~1 & Gas Cons. Commission .-. '" Anchorr .~ : ~ . :~ C. OOK INLET"' PLAT'FOR:MS; EOPE -.? Section Three Sidetrack Proeram 3.1 Sidetrack Program This program beans where the abandonment program for K26 ends. The objective of this part of the program is to sidetrack the well with an 8" whipstock in the existing 9 5/8" casing at +/- 8700' MD-RT. The well will then be drilled down to a depth of +/- 11228'MD-RT. A 7" liner will be nm into the open hole and cemented in place. Note, that the milling fluid is planned to be a simple spud mud. 19. RIH with an electric line set C.I bridge plug and set two fret below the nearest casing collar to 8700'MD-RT. POOH with wireline. 20. Make up the 8"OD Weatherford Whipback Retrievable Mechanical Trip Whipstock on an 8.50" OD insert type starting mill with bit sub, and a joint of 5" drillpipe and MWD. RIH on drillpipe to 30 ft above the C.I bridge plug. Note: Check the string weight up and down at this stage and record in the morning report. Check also the pulse on the MWD tool. 21. Orientate the whipstock malting sure that the pulse on the MWD tool is constant. Continue to Run in the hole for another 20 ft. Check MWD readings once again. 22. Lower a further 10 ft to the top of the C.I. bridge plug and set down with 10,000 lbs to set the whipstock. Set down 20,000 lbs to shear offthe whipstock. 23. P/U 10 ft above the whipstock and start the pumps and start rotating at 80 to 100 RPM's. 24. Slowly lower the string watching for a torque increase. When detected mark the pipe and start milling the pipe for two feet only. 25. Disengage the rotary, pick up, circulate the wellbore clean, prior to pulling out of the hole. L/D the starting mill and the MWD tool. 26. Make up an 8.5" Weatherford insert mill, an 8.5" Watermellon mill, bit sub, to 5" drillpipe string and RIH. Ten ft above the top of the whipstock start the pumps and rotary to 80 to 100 RPM's and start lowering the string until a torque increase is noticed. Mill 20 ft at this stage, this will be l0 ft of easing and 10 ft of open ho~le. Circulate bottoms up prior to POOH. Note: Depth control is critical. All crews to monitor tally's rigorously. 27. Make up 8.5" Weatherford insert window mill~ two 8.5" watermelon mills and 1 jt of heavy weight drillpipe, crossover sub, 9 off 6 3/4" drill collars, crossover sub to ddllpipe and RIH to 10 ft above the top of the whipstock. Revision One Unocal Alaska Anchorage June 2, 95 12 Section Three Sidetrack Pro~ram 3.1 Sidetrack Pro~ram (Continued) 28. Engage the pump and rotary to 80 to 100 RPM's and lower the string watching again for aa increase in torque. Continue millin~ to the bottom of the window. Continue reaming and polishing the window until the up and down drag is 5000 lbs or less with the rotary disengaged. Circulate bottoms up prior to POOH. 29. Make up the 8 1/2" drilling assembly, mud motor and MWD and sidetrack the well with 8 1/2" hole from +/-8,700' to 11,228' MD-RT following the directional plan. Note: The new well number to be designated upon commencement of the sidetrack. Note: Note: Extreme caution should be taken while tripping and drilling in the 8 1/2" hole especially if coal sections are encountered. Numerous stuck pipe incidents occur in the Cook Inlet area relating to being stuck ia coals. All driller's should remain alert for all drilling breaks and assume that all drilling breaks are coals. If drilling breaks are encountered the string should be picked up immediately and the string worked back to bottom very cautiously, as detemfin~ by the Drilling Foreman. correlation.Mud L°gger's to alert the driller's °f expected coal seams bY using the K26 well f°r ~~-----~)~ Note: All open hole trips to be monitored closely for tight hole. Note: Estimated TD is approximately 11,228' MD-RT. Actual TD will be the depth at the base of the pay zone plus 200 ft. 3 0. At TD circulate bottoms up prior to POOH. 31. Condition the well and log as per the logging program. Note: An additional clean out nm will be considered if difficulties were experienced logging the well. 32. Run and cement a 7", 29 ppf, L80 liner with standard buttres,s couplings per the cement program. TIW will be supplying the float equipment, liner hanger, cement manifold etc. 33. POOH after cementing the 7" liner in place. 34. 35. P/U a 6" bit and 7" casing semper as required and RIH while P/U 3 1/2" drillpipe. Clean out the liner top. Pressure test the liner to 3500 psi. Displace the well to filtered inhibited seawater. RECEIVED Revision One Unocal Alaska Anchorage June 2, 95 Section Three Sidetrack Program 3.1 Sidetrack Pro~ram 36. 37. Run a CBL/VD~G~CCL log from ETD to 200 ft above the top of the liner. Run a gyro multishot survey from ETD to 200 R above the whipstock. Note: Proceed to Section Four the Completion Program. Revision One Unocal Alaska Anchorage June 2, 95 RECEIVED 14 Section Four Completion Pro~ram 4.1 Completion Program 38. Run and set a Baker 7" FB-1 permanent packer with 4" bore on wireline. Set the packer at the required depth to ensure that the bottom of the tubing is 50 t~ above the top of the Hemlock sand. Ensure that depths are correlated to the CBI. ffVDL log. 39. Make up the 3 3/8" tubing conveyed perforating guns and spacer gun.~. Note: Intervals to be perforated will be determined agmr the logging program. Run the 3 1/2" completion as per the completion schematic. Run a Baker "V" plug in the bottom XN nipple. Pressure test the tubing to 300 psi at~r making up the XA SSD and just prior to stabbing the tubing assembly through the 7" Baker packer. Note: When pressure testing, ensure that the annulus is open as there is a back-up hydraulic firing head incorporated in the TCP system. The TCP engineer is to be on the drill floor for all pressure tests. Note: Dri~ all tubulars to ensure that the TCP firing mechanism and TCP gun drop shirring tool pass through the internal diameters of all assemblies. Pull the Baker V plug from the XN nipple. Circulate slowly while stinging the seals through the packer. Do not exceed 500 psi pump pressure. Test the annulus to 1500 psi. Ensure that there are no plugs in the tubing during the pressure test. Again the TCP engineer to be on the drill floor for all pressure tests. P/U space out and install the control line and tubing hanger. Test the control line to 5000 psi. Land the tubing hanger in the tubing spool. Make up the fie down bolts.and pressure test the annulus to 1500 psi. Install a back pressure valve/plug in the tubing hanger. Nipple down the BOWs and riser. Install and test the Xmas tree. Check the tree alignment is as per the Production Departments requirements and test the tree to 5000 psi ..... ' Release the fig and hand the well back to production for offioading and perforating proced~. 40. 41. 42. 43. 44. 45. 46. 47. 48. Revision One Unocal Alaska Anchorage June 2, 95 C'EIV E D dUk/ - ,~ 1~)95 ~8 Gas Cons. Commission ~chor~ - "':-r,,n~j Salmon Platform Conductor Slot: 25 Well K26 RD RT to Mud Line: 175' Run Bate: TBA Proposed Completion Schematic Water Depth 73' Date' May 28, 95 RT to Tbg Hgr: 49' Producing Well ,5 1/2" Single String Completion ~.: ~ dept~, or. r~r.r~nc*d ~0 ~ ~, ~ Depth (~T) OD ID ___. __. ~ 24"X1~ ~/8"~ 5/8" : W~ , 24"e ~ , i ~eo~ ~ w B RD x ~S XO 3.812 2.99 ~0'~ ' ~ ~ ' ,~ G~. U~ ~ 5.625 2.99 13 3/8'~~ ~ i~ wAh 8RD~ B~ XO ~'~ ! i ~" ~ ~s xo 5.625 2.99 i ~~ 5.625 2.99 , i ; i 5.625 2.99 IJ 5.625 2.99 ! J 5.625 2.99 ~ 5.625 2.99 i ~ 5,625 2.99 ~ J 5,625 2.99 5,625 2.99 I ~ 5.625 2.99 i 3 1/2.9.~ppf.~.~ rublng 5,812 2.99 J T~ of bner ha~er ~ ~00'~ -- -- ~ ~ 1/2" So~r .lidin; ~ 4.437 2.81 ~7oo'~ ~ ~ 7-~,, ~-~ 5.625 3.25 , ~d~n pacer w~ 5" ~ 4.187 2.68 : millo~ e~on ~ ~', "~" ~, 4.500 3.00 / ~ aa~ ~ o~ sub w/XO Pe~s to be - 11,2~'Rf Unocal Alaska Business Unit McArthur River Field 06105195 Check on Maximum Anticipated Surface Pressure For K26 RD. General Data Mud Weight Shoe Depth (9 5/8' Shoe) Estimated Fracture Gradient (At 9 5/8' shoo) Total Depth Bottom Hole Pressure Gradient Gas Cn-adiem (Assumed worst case) 8.5 ppg 8,700' MD-RT 6200 psi 11,228' MD-RT 4600 psi 0.442 psi/ft 7,732' TVD-RT 0.8 psi/ft 10,106' TVD-RT 0.45 psi/ft 0.0 psi/f~ Worst Case Assumed A gas kick taken resulting with the following wellbore situation: 3/4 of the hole filled with mud + 1/4 of the hole filled with gas Note: The K26 RD well has an oil bearing objective and not a gas objective. For maximum surface pressure therefore we have, Maximum surface pressure MSP MSP MSP = Bottom hole pressure - Hydrostatic pressure = BHP -(3/4 Mud + 1/4 Gas) = (10,106'0.45) - ((0.75'(10,106'0.442) + (0.25'(10,106'0) = 1,197 psi Check on hydrostatic pressure at the shoe with Maximum Surface Pressure The greatest hydostatic pressure at the 13 3/8" shoo.(HPsh) is when th~ glks'bubble reaches the shoe, if a constant BHP is applied. A conservative estimate would be th~ maximum s~~pr~e, pJq~ ~ hydrostatic pressur~ at thc casing depth. I-Ienc~, t< Ll: i VkD I-IPsh = MSP + I-IPesg J U N - '~5 ].c) 9 5 HPsh = 1,197 psi + (7,732 * 0.45) HPsh = 4,676 psi ~.!~ska 0~1 & (~as Cons. Commis~10n Anchora i:~ This is less than the fracture gradient at the shoe and should therefore be sufficient to handle a well kick. :'ected by : jones For: G BRANDER plotted : 20-Mar-g5 Reference is K-26 Rd#1 Version il2. .'::rdinotes are in feet reference s!ot l¢4-25. Vertical Depths are reference ~edhe~3d. --- Baker Hughes INTEQ --- Structure : KING SALMON Platform Field : I~cArthur River Field Well : K-26Rd Location : TBU, Cook Inlet, Alaska Point WELL MD KOP 8700 End of Droo 9577 'Target 11028 iEnd of Hold 11228 PROFILE DATA ,nc Oir 'r'vo No~h East Deg/t0C, 36.68 347.34 7732 3240 -1778 0.0C 16.81 357.32 8334 3538 -1828 16.81 357.32 9915 4015 -1850 O.OC 16.81 357.32 10106 4073 -1853 O.OO 7o0o -- 7200 ,. 7400 7800. 780O I I V 920O. 980O 98OO 1 o200, 2800 27.12 "?~ 1 i I 1 i : I i i i : i i i i ; i i 1 ,3000 3200 3400 361X) 3800 4000 4200 4~ 46~O 4800 Scale 1 : 100.00 Vertical .~¢fl~n ~ 557.3,2 ~ ~ reference 0.00 S. 0.DO [ lmm Slot ~4-25 2300 I N 2.68 DEG w 4t55'(TO TD) AVERAGE ANGLE 16.81 DEG 2200 I 2100 2000 Wesf 1900 1800 ! i i i End at O~p & I'~m KOP - .~14~0¢.~ Pok'l ~ 1700 ,I _4.!,00 _4200 - _4100 . .4~XX> _3900 _ _3800 - _370O A I I z .310O O RECEIVED JUN -~5 1!-'95 011 & Gas Cons. ComrnjssJo[J Anch0r~ , UNOCAL KING SALMON PLatform,K-26Rd McArthur River FieLd,TBU, Cook Inlet, ALaska PROPOSAL LISTING Page 1 Your ref : K-26 Rd#1 Version #2 Last revised : 20-Mar-95 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOFt Sect 8700.00 36.6~ 347.34 7732.]2 3964.89 N 1911.14 W 0.00 8800.00 33.71 348.12 7814.03 4021.20 N 1923.40 W 3.00 8900.00 30.75 349.04 7898.61 407'5.46 N 193].98 ~ 3.00 9000.00 27.80 350.12 7985.84 4121.54 N 1942.84 ~ 3.00 9100.00 24.85 351.44 8075.46 4165.30 N 1949.97 ~ 3.00 3319.30 KOP - Sidetrack Point 3376.12 3428.82 3477.26 3521.31 9200.00 21.92 35].09 8167.23 4204.62 N 1955.34 g 3.00 9300.00 19.02 355.22 8260.90 4239.40 N 1958.95 g 3.00 9376.69 16.81 357.32 8333.87 4262.94 N 1960.51 ~ 3.00 9500.00 16.81 357.32 8451.91 4298.56 N 1962.18 g 0.00 10000.00 16.81 357.32 8930.54 4443.01 # 1968.93 g 0.00 3560.84 3595.75 3619.33 End of Drop & Turn 3654.99 3799.60 10500.00 16.81 357.32 9409.18 458?.46 N 1975.68 ~ 0.00 11000.00 16.81 357.32 9887.81 47'51.90 N 1982.44 ~ 0.00 11028.40 16.81 357.32 9915.00 4740.11 N 1982.82 ~ 0.00 11228.40 16.81 357.32 10106.45 479?.89 N 1985.52 W 0.00 3944.20 4088.81 4097.02 TARGET 4154.86 TD / 7" Casing Pt RECEIVED Gas Cons. C:mmis~ion Alt data is in feet unLess otherwise stated Coordinates from SE Corner of Sec. 17, TgN, R13W SM and TVD from weLlhead (lO0.00 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 357.32 degrees. Declination is 0.00 degrees~ Convergence is -1.40 degrees. Ca[cu[ation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL KING SALMON Platform,K-26Rd McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : K-26 Rd#1 Version #2 Last revised : 20-Mar-95 Cc~ments in wel[path MD TVD Rectangular Coords. Coa~ent 8700.00 7732.32 3964.89 N 1911.14 W KOP - Sidetrack Point 9376.69 8333.87 4262.94 N 1960.51W End of Drop & Turn 11028.40 9915.00 4740.11N 1982.82 g TARGET 11228.40 10106.45 4797.89 N 1985.52 ~ TD / 7" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Sot MD Sot TVD Rectangular Coords. Casing n/a 77'52.32 3964.89N 1911.14~ n/a 7732.32 3964.89N 1911.14~ 13 3/8" Casing n/a 77'52.32 3964.89N 1911.14g 9548.42 8498.26 4312.55N 1962.83~ 9 5/8" Casing n/a 7732.32 3964.89N 1911.14g 11228.40 10106.45 4797.89N 1985.52~ 7" Casing Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised K-26 ST Rvsed 14-Mar not specified 9915.00 4740.11N 1982.82~ 25-Ju[-94 RECEIVED ,jtJ - 5 ALt data is in feet unless otherwise stated Coordinates from SE Corner of Sec. 17, T9N, R13W SM and TVD from wellhead (100.00 Ft above mean sea [evel). Sottom hole distance is 4474.37 on azimuth 335.54 degrees from wellhead. Total Dogleg for we[[path is 20.30 degrees. Vertical section is from wellhead on azimuth 357.32 degrees. Declination is 0.00 degrees, Convergence is -1.40 degrees. Calculation uses the minin~mcurvature method. Presented by Baker Hughes INTEQ Time Curve For King Salmon Well K26RD. Datum is Rotary Table 7000 8000 go00 10000 11000 12000 Time (Days) d U~ - 5 1995 Gas Cons. Commission RE IVED ,JU -ti 199,5 Oil & as Cons. Corn mchor; ..,~ Fracture Pressure and Pore Pressure Graphs Versus True Vertical Depth Notec An ossun'~l Rotc~ Table height ~t' lgOlt hoe been u~l [er all dat~ 1000 2000 4OO0 500O 6OO0 7000 8000 90O0 1000O 11000 0 I ! i i i i i ! i i i ! i i ! i I i i ! ! ! i i i ! I i i I i I ! i I i i ! I .' .i....!....i ...... i...i...i...i ...... i...i...i...i ..... i...i....i...i ...... i...i...~.4. ...... i...i...i...i ....... ~...i...i...i ....... i....!...-!--..i ...... i...i...i..4 ...... i...i...i...i... -'t~."":_.~:!: ..... H---H-..!..-i...i.-.i...i-..+H--.i ...... H...H ...... i...i...H ...... H---H ....... i...H...i ...... H,..H ..... i...i...i...i..- ~~~m!~i~i...i~4~...~...i...:.~L~`...~i~i...:~i~i~....~.~.~..~ ...... i...i...i4 ....... 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I 'I',- ,' : : : : : : .' ~ : .' .' : : ; : : : : · : -'?"i'"t'"! ....... i'"i'"i-..i ...... i.-.i-..r-.i ...... t'-t...i...!'.-,,-.i...i...t..t ...... ?..i...i..-i ..... t."i...i..'i'":'-'i'"t"t'"i ...... i...i...~...t...::::[:: ii i i ii ii ii ii iiii ii ii' i iii iii i i ii i i iii i ii i 10(X) 2000 ;~00 44~0 5000 SO00 7000 8000 9000 1 Symbol Legend O Baker Froc Data i~ Oraylin9 Fra~. Data ~ Monopod Frac. Data · Oran. Pt. Froc, Da[a [] Dillon Frac. Data · Anna frac. Data /% King Salmon Frae, Data Pressure (psi) R[C~IV~D jUN -5 1.995 A!~,ska Oil & 6as 6ons. 6ommisSi~y 26, 95. OO01.SpO Anchor,-'.'." Fracture Pressure and Pore Pressure Graphs Versus True Vertical Depth Not~ .qN a$,umd~l It~y T, bll height ~f 100t~ ha~ b.en u~l for ~ll dal~ ~"h'?'?"i""?"h't"'?'i ........ i'"'i'"~~~"i'"'t ....... i'"i'"'i'"'h'?'T'""i""h'i .... ~-...........:.....:............i.... :....... o. o ..:. o..., ........ ;.o.o :.... ? oo........;.ooo;..., :..o.:. o. o ..~ ........ ....o. :. oo. ;.. oo ?.oo.:.. o..o; ....... :...o; ........ .~.....~....;..o. ;o.....:.....~. oo..~ o..o ;..o.: ----.'....~;....~.....;....i....i....i..-.~......; ........ i....;.....-.'....~-...i....i..- F.--i....~...' .... i....i...-;......~...~....~....; ....... : ......... .' .... ;.-..:.....~.. ..'".-:...-: .... i....i....!...'.i......:...;...~.*..!..~- -..i ..... i.,.-,~ ..... i--,.i,,,.i-,,-i--.,4 ..... i ........ i,,,,i,,,,-~,,-,~,,.,i.-,.i .... i,-,,i,..,i ......... i,,,,i,,,.i,,,,;~,,,;~.,,,i,.,,i,,,,i ........i..,.i,,,,i,,,-i ..... i,,--i,,-.i,,,,i--,-i .... -"F'H'"'H'"'H""H'"' .... 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L.[..i4\..;.....;....L..L.i .... ~.., ..... ,.....~ ..... ,....,.?...?....~ ..... : ........ ,.~. ..... ,....,.....:....,....,...?:?:.. ....... :....,....?...?.:....:....,....?.., ........ :.::;L;L;i:;:5...~ ..... :...?..., .... -"'.""' ?"'?'"'~'"'!'"":'"":'"'?'"':' ........ !'"".."" ?"' ?""..'""!""!""'.-'"' ? ......... i'"'!'"' ?'"?"'?'"'..'""!'""..'"'~ ........ ..'""..'""!'"' ?'" ~ "?'"'~""!"'": .... -..~....,....~....i....~....~....~.....~....~ ........ ~....~....,....~....~..4....~....~.....:- ........ i....~....~.....~...,....~....~....~....~ ........ i-~i-~ .~+...-k-.k-.i .... ........................... 110(0) i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i O 5 lO 15 20 Symbol Legend O Baker Froc Data 0 Grayling Frae. Data ~7 tdanopod Frae. Data · Gran. Pt. Frae. Data [] Dillon Frac. Data · Anna Frac. Data A King Salmon Frae. Data Pressure (PPg)R E C E IV E D JUN ~-fi 199,5 ~,!~s~ Oil & 6as 60ns. 6ommissiorlvtay 26, 95. oo02.sPo Anchor~. :' Cement Production Liner Well Information PREVIOUS CASING SIZE 9 5/8 IN. HOLE SIZE 8 1/2 IN. LINER SIZE 7 IN. TOTAL DEPTH 11228 FT. 8700 FT. TOP OF LINER 8300 FT. TOP OF CEMENT 8100 FT. EXCESS 100 % RECEIVED dUl~ - 5 1~5 A!~ska Oil & Gas Cons. Anchor~,~ Commission Cement Production Liner Caiculatiort= SPACER: (1022 ft fill) 1022 ft * 0.2747 ft31ft * 0 % TOTAL SPACER CEMENT: (3128 ft fill) 200 ft * 0.2747 ft3/ft * 400 ft * 0.1438 ft3/ft * 2528 ft * 0.1268 ft3/ft * 0% 0% 100% TOTAL CEMENT SHOE JOINT VOLUME: (80 ft fill) 80 ft * 0.0371 bbl/ft TOTAL DISPLACEMENT VOLUME: (11228 ft casing) 8300 ft * 0.0178 bbl/ft 2928 ft * 0.0371 bbl/ft DISPLACEMENT VOLUME TO SHOE JOINT: 256.18 bbls - 2.97 bbls = 280.71 ft~ = 280.71 = 50 bbls = 54.93 ft3 = 57.51 ft~ = 641.15 ft~ = 753.59 ft3 = 137.18 bbls = 16.69 = 2.97 bbls = 147.42 bbls = 108.77 bbls = 256.18 bbls 253:[! 1 bbls RECEIVED a!aska .0"u & 6as Coas. Oommbsion Anchorz., VENT OUT~IDE WlNDWALL$ VENT UP DERRICK 4' PANIC LINE SET AT 4O 4" 5,000 PSI BALL VALVE 10,000 PSi HTD. CHOKE \ GUAGE PORT'-~ CHOKE. 8UFF~ TANK MUD CAS SEPERA TOR ~ ~PHON UNE j TOSHAKER ~UO RETURN UNE RECEIVED Cement Production Liner Job Recommendation OPTION # 1 ADDITIVES PLACED IN THE MIX WA TER FLUID 1' SPACER DUAL SPACER Top of Fluid: Calculated Fill: Fluid Volume: FLUID 2: CEMENT Premium Cement .25 % CFR-3 (Dispersant) .22 galYsk HALAD®-344L (Fluid Loss) .2 % HR®-5 (Retarder) Mixed With Fresh Water Fluid Weight: Fluid Yield: Fluid Water Ratio: Total Mixing Fluid: Top of Fluid: Calculated Fill: Fluid Volume: Calculated Volume: Shoe Joint Volume: Total Volume: Proposed Volume: FLUID 3: DISPLACEMENT Total Displacement Volume: Spacer On Top Of Plug: Displacement to Shoe Joint: 7078 ft 1022 ft 50 bbls 15.80 lb/gat 1.15 ft3/sk 5.0 gal/sk 75.5 bbls 8100 ft 3128 ft 137.18 bbls 655.5 sks 14.51 sks 670.00 sks 670 sks 256.18 bbls 0 bbls 253.21 bbls i l RECEIVED ,;UN -5 1,995 Oil & 6as Cons. Commission Cement Production Liner Co~t Estimate OPTION # 1 ADDITIVES PLACED IN THE MIX WA TER Price Ref Descriotion -- 504-O43 507-153 507-779 507-395 500-207 501-525 001-016 091-003 PRBMKYM CEMENT CFR-3 HALAD 344L HR-5 BULK SERVICE CHARGE BLENDING - HALLIBURTON CEMENTING CASING OPERATOR TIME - CEMENTING 670 170 148 130 670 670 1 2 3 U/M U. ,nit Price Total SK $ 14.50 $ 5,829.00 LB 5.40 576.72 GAL 82.20 7,299.36 LB 3.55 282.58 cfr 1.35 542.70 Cfr 0.95 381.90 JOB 1,995.00 1,995.00 DAY 690.00 4,140.00 MAN DISCOUNTED TOTAL $ 21,015.66 NOTE: Service Location - Kenai RECEIVED Anchor~- ', J Driiling Fiuids,.,. . / --: _. ;._ ~ ~ : -: -- ::- - ~., ~.- UNOCAL DRILLING FLUID PROPOSAL K-26 RD DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS MILLING/KICK OFF (8050' M.D. - 7150' TVD) GENERIC MUD #2 M-I GEL/M-I BAR/GELEX/ CAUSTIC/BICARB/BIOZAN/ SAPP/TANNATHIN HOLE CLEANING/CEMENT CONTAMINATION/METAL SHAVINGS TREATMENTS/PROCEDURES 1) Build milling mud system with prehydrated bentonite and fresh water. a) Treat water with Soda Ash as required to reduce calcium content to 40± ppm. b) Pre-hydrate 10-15 lbs/bbl bentonite. Add Gelex at 5:1 ratio of Gelex to M-I Gel. 2) Use all solids control equipment. Raise viscosity to insure hole cleaning while milling. Use Biozan to increase low shear rate viscosity. 3) Pump high viscosity sweeps to clean hole. Run ditch magnets. ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point pH 82'6 - 10.0 ppg 70-250 sec/qt 12-25 cps 20-60 #/100ft2 9.0 - 9.5 DM-155 .WP (3/95) INVOLVED IA13.111TY t"l AIIRF: RECEIVED JUN - Anchor: = Driiling Fiuids,. . . UNOCAL DRILL~G FLUID PROPOSAL K-26 RD DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS 8,050' - ll,Z~g' 8-½" HOLE GENERIC ~,~1~ #2 M-I GEL/M-I BAR/SODA ASH/ AQUAPAC/GELEX/TANNATHIN/ SODIUM BICARBONATE/ CAUSTIC/SPERSENE CF/ RESINEX/SOLTEX/ XANVIS/LOWATE/LIQUID CASING HOLE CLEANING/TIGHT HOLE/BIT BALLING/ HOLE ENLARGEMENT/GAS KICKS/COAL SLOUGHING/ SEEPAGE LOSS/DIFFERENTIAL PRESSURE TREATMENTS/PROCEDURES 1) Use the milling mud to kick off cement plug. Treat this fluid as required to avoid excessive cement contamination. Drill 10' of new hole, displace to new mud system. Displacing to new mud system is recommended because of incorporation of metal cuttings and cement contamination. 2) Build additional volume as required. 3) Pump viscous sweeps as required. 4) Control density with barite, fresh water, .inlet water, and solids control equipment. Dump- a~l sand ~traps as required. Increase mud weight only if required by hole conditions. DM-155 .WP (3/95) ///~i~F_,N V IRON M E NTA LLY INVOLVED NOTE: SEE REVERSE SIDE FOR LIABILITY CLAUSE REC'E1VED Anchor,~ 5] Report drill solids analysis on mud check sheet. 6) Report hydraulics calculations on mud check sheet. 7) Use Defoam-X if foaming becomes a problem. 8) Add Soltex and Resinex as required. ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss pH MBT Drilled Solids 9.5-11.0 ppg 45-80 sec/qt 15-20 cps 12-25 #/100ft~ 8/12/20 8-12 cc 8.5 - 9.5 < 20 lbs/bbl < 50 lbs/bbl Note: This mud program is a guideline only. should dictate actual mud properties. Hole conditions DM-155. WP (3/95) RECEIVED jUN - 5 !995 /~.!~s~ Oil & Gas Cons. Commission Anchors .~ ////F-H V I RONM ENTA I I Y INVOLVED 172 bbls. ~ 6 bbls/ft. ~.6 bbl/in. SHALE SHAKERS t 40 bbls. ~6 b~l,B~. ~.~ b~V~. DE~ASSER 248 bbls. 3~ bb~,Bt. CHEM. £.~ bbl/in. MIXER 248 bbls. 2.6 bbl/in. 74 bbls. ~ ' 9 bbls/fL DESILTER .8 bbl/in. RECEIVED JUN- ~J~l & Gas Cons, Commiss[.oQ Anchor~ dttlfld .9 .,Ol I .9 I t I i i ,,9 n :~ .9 I I i i .Ol _3A-lVA 3.LVO .0l 'ON cl~l')d ontq PlO~_,-I l 'ON dPtfld 0[~1 ~10~_,a 3A'~A T1V8 ~ ~A'~'A dlg~ ~ ~TZI'I~nD~ BOJJOB ~ ON~O3-1 ]NFl t:10 dOd SNflOOI]Pi ............. NOLLD[I$ 3NFl ............................. X'lddflS 83ddOH NSfU_~ ,~l.?,ddOH ................................ ~.'Iddfl~ PLUG VALVE FROM CEMENT PUMP 2' I.D. 10,000 PSI WORKING PRESSURE STAINLESS STEEL ARMORED HOSE !0,000 PLUG VALVE 3 1/2 1.0. X 5,000 PSI ROTARY HOSE SWIVEL /-2~ STANDPIPE /PLUG VALVE ~ ~__ BLOW DOWN FROM MUD PUMP 4" X 5,000 MUD VALVE FLOOR L~v~c 1,7 5/8" x 5,ooo ~ BLOWOUT PREY~ STACK FILL-UP. KILL LINE ANNULkR BOP 2 IVi2000 psi FLOW : 203/4~ 3000 psi / BLIND RAMS | 20~ 3000 psi ~ ' ]DR~.LING~ _ ~~ ~1~~ SPOOL ~l~ll ~o~ooo p~~ ~ 5000 psi ] ~, 4" 5000 I' ~ ~0~/~'8000 psi CHOKE ps~ RECEIVED JUN - 5 199,5 Alaska Oil & 6as Cons. Commission Anchora :~, ~ RISER CQQK INLET"' P TFORM'. 1. Type of request: ~. STATE OF ALASKA AL,a/" ~ OIL AND GAS CONSERVATION COMIV -"ION ~'~ /'! ~'~jj ~ '~ ~' '~'' APPLICAI/ON FOR SUNDRY APr'ROVAL- - ' ,. Abandon X_ Suspend __ Operafion~ shutdown__ Re-enter suspended well__ Alter casing__ Repair well __ Plugging __ Time exter~lon __ Stimulate __ Change approved program Pull tubing Variance _ _ Perforate__ Other_ _ 6. Datum eleva~n (DF or KB) 2. Name of Operator UNION OIL COMPANY OF CAUFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of Well: ~X 4. Location of well at surface KING SALMON PLATFORM 725'N & 133' W OF SE CORNER, Sec. 17, T9N, R13W, SM At top of productive interval At effective depth4760' N & 2100' W OF SE CORNER, Sec. 17, TON, R13W, SI~L. F.)-~ ~f'--'~ ~:::~')~''?'''' ~'"'~!i 4801' N & 2108' W OF SE CORNER, Sec. 17, T9N, R~{~V~ S~72 ' At total depth 5083' N & 2214' W OF SE CORNER, Sec. 17, T9N, R13W, SM 100' KB feet 7. Unit or Property name TRADING BAY UNIT 8. Well number K-26 9. Permitnumber 93-165 10. APInumber 50-733-20097-03 11. Field/F'ool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 10,420' feet Plugs (measured) 9,163' feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 350' 24' Driven 350' 350' Conductor Surface 29.38' 13-3/8' 2050 sxs 2938' 2718' Intermediate 9359' 9-5/8' 2700 sxs 9359' 8197' Production Liner 10,973' 7' 550 sxs 10,973' 9668' Perforation depth: measured , 0148'- 10372', 10564'- 10814' RECEIVED true vertical 89 23'-9238', 9 295'- 9523' Tubing (size, grade, and measured depth) 3-1/2', 9.2#, L80, TDS to 10,045' MD ~,.~la~)F,,i~l & Gas Cons, Commission Packers and SSSV (type and measured depth) 7' Baker SAB-3 packer @ 9990' MD 3-1/2" Baker SSSV ~ 343' MD 13. Attachments Description summary of proposal X_ Detailed operations program_ _ BOP sketch X_ 14. Estimated date for commencing operation ~15. June 14 16. If proposal was verbally approved Oil X_ Gas Name of approver Date approved Service 17. I hereby certify that the fqr"~gp~g is t-~Ne ./~.~d co?t'.ept to the best of my knowledge. Signed G. Russell Schmid tT.~/,~.' .~l~t ~/~'~~tio Drilli" ~'¢"~ ngMan ag er FOR COMMISSION USE ONLY Status of well classirmation as: Suspended~ Date Jur),e 2, 1995 Plug Integrity ~ BOP Test Location clearance Conditions of approval: Notify Commission so representative may witness Mechanical Integrity Test___ Subsequent form required 10- Approved by the order of the Commissio~~'~"'~ Form 10-403 Rev 06/15/88 Commissioner - Date SUBMIT IN TRIPUCATE List of Attachments Attachment One Description Summary of Proposal. (See Section 2.0, Pages 8 - 11 of the Drilling Program) Attachment Two BOP Sketch. RECEIVED · ,=LL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev [] redrll~ aery [] /20 7o ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 6. · 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Permit fee attached ................... ~ Lease number appropriate ................ ~ Unique well n~e and n=ber ......... ..... .~ Well located in a defined pool ............. ~ Well located proper distance from drlg unit bounda~..~ Well located proper distance from other wells ..... ~) O~era~or n~ a~propr~a~ ~on~ ~n ~or~ ......... ~ Pe~it can be issued without conservation order .... ~ Permit can be issued without administrative approval.. Can pe~it be approved before 15-day wait ....... ~ Surface casing' protects all known USDWs ......... C,,,,a,.,,a,,,o,,,,u,a,,o,,o,,,,,or,,,,,,,,.., CMT vol adequate to tie-in long string to surf csg . . . CMT will cover all kno~ productive horizons ...... ~ Casing designs adequate for C, T, B & pe~afrost .... ~ Adequate tankage or rescue pit ............. ~ If a re-drill, has a 10-403 for abnd~t been approved. Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... ~~~ Drilling fluid program schematic & equip list adequate .~ BOPEs adequate ..................... BOPE press rating adequate; test to ~~ psig~ i ut op ~ ....... ~ Is presence of E2s gas probable ............ ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~. 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... ~/ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:%FORMS%cheklist my 03~4 II