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Home My WebLink About2019-01-31_319-047RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION !AN 31 2019 APPLICATION FOR SUNDRY APPROVALS 1. Type of Bequest: Abandon j f Plug Perforations ❑ Fracture Stimulate ❑� Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑J Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Great Bear Petroleum Operating Exploratory ❑✓ Development ❑ 214-208 3. Address: Stratigraphic ❑ Service ❑ fi. API Number: 310 K street. Anchorage, AK 99501 50-223-20029-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Alkaid #1 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 391704 1WILDCAT 111. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft). Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3331 10 3/4" 3331 3331 5210 2470 Intermediate Production 8595 7 518 8595 8261 6890 4790 Liner Perforation Depth MD (ft): 8150 Perforation Depth TVD (ft): 7830 Tubing Size: 2 718 Tubing Grade: L-80 Tubing MD (ft): 8150 Packers and SSSV Type: PLS - Packers and SSSV MD (ft) and TVD (ft): 8100 12. Attachments: Proposal Summary Detailed Operations Program Q Wellbore schematic U4 BOP Sketch ❑ 13. Well Class after proposed work: Exploratory ❑✓ Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for Commencing Operations: 1-Mar-19 15. Well Status after proposed work: OIL ❑ WiNJ ❑ WDSPL ❑ GAS ❑ WAG ❑ GSTOR ❑ GINJ ❑ Op Shutdown ❑ Suspended ❑ SPLUG ❑ Abandoned 0 16. Verbal Approval: Date: Commission Representative: r. + n --y �ciuiy LIM ula VICUUu"y is uua aiiu uia NrU[:euurU dpprUVeU nereln wm not be deviated from without prior written approval. Authorized Name: Michael Duncan Authorized Title. VP O erations w _ 1 _ Contact Name: Michael Duncan Contact Email: _michael ftre Contact Phone: 817.240.3865 Hutnorizea Signature: Date: 1/2512019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 61q r0L1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Initial Injection MIT Req'd? Yes ❑ No ❑ ing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY i by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 412017 Approved application is vr0fR21rGh j N the date of approval. Submit Form and Attachments In Duplicate 6refi-t,,6mr PETR0Lf� 1i 3705 Arctic Blvd, Sifte 2324 Anchorage, AK 99503 (907)868-2070 January 25, 2019 Mr. Hollis S French, Chair Alaska Oil and Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Mr. French Great Bear Petroleum Operating LLC ("Great Bear") hereby applies for sundry approval to complete and test the Alkaid # 1. This well is currently in a suspended condition. Please find the attached Form 10-403 Application for Sundry Approvals, This application also includes the following: 1) Alkaid Completion Procedure 2) Wellhead drawing 3) Various wellbore diagrams representing various stages of the proposed work 4) Fracture chemical disclosure 5) Fracture geometry results of stimulation modeling 6) A review of Maximum Anticipated Surface Pressures (MASP) The designated contact for reporting responsibilities associated with this activity is: Michael Duncan 817.240.3865 Michael@ reatbear etro.com Sincerely, Michael Duncan Great Bear Petroleum Operating LLC or sw(Ir, ET R 0 L Eu ivi 3705 Arctic Blvd, Suite 2324 Anchorage, AK 99503 (907)868-8070 January 25, 2019 Alkaid completion procedure Written by Michael Duncan, Great Bear Petroleum January 25, 2019 Contents StandingOrders: ........................................................................................................................................... 2 Movein, rig up, and well check.................................................................................................................... 3 Ifnecessary, thaw well................................................................................................................................. 3 Prepareand log well..................................................................................................................................... 4 Complete and Test the Alkaid Zone of Interest(ZOI)................................................................................... 4 Alkaid completion contingency pan............................................................................................................. 5 Suicidesqueeze........................................................................................................................................ 5 Alkaid ZOI fracture stimulation and test................................................................................................... 6 PlugAlkaid ZOI.............................................................................................................................................. 7 Shallowerremedial cement work................................................................................................................. 8 WestSak Completion.................................................................................................................................... 8 WestSak Plugging......................................................................................................................................... 9 UgnuCompletion and Test..........................................................................:.............................................. 10 Plugwell......................................................................................................................................................10 11 Standing Orders: 0 Always maintain appropriate well control equipment, including a stabbing valve on the rig floor. Ensure the stabbing valve is kept in the open position and meets the thread connection for tubulars used. • Ensure rig has appropriate gas detection in place per regulations 0 Maintain a wellbore volume of kill weight fluid (9ppg+) in rig tanks at all times January 25, 2019 Move in, rig up, and well check 1. Move in and Rig up 2. GE service hand to inspect wellhead and verify condition. Make necessary repairs. 3. Verify no pressure on wellhead and remove VR plugs a. See Attachment A: Wellhead drawings for wellhead configuration b. See Attachment B. Alkaid current configuration wellbore schematic 4. Nipple up pump to outer annulus. Pump small volume of diesel to verify annular injection. 5. Nipple down from outer annulus and nipple upon inner annulus 6. Circulate diesel to verify wellbore is not frozen 7. Install two-way check in tubing hanger 8. Ensure appropriate 3,000 psi, dual ram with annular preventers are selected 9. Nipple down tree, nipple up and test BOP's 10. Remove two-way check If necessary, thaw well 11. If necessary, TIH with 2 7/8" tubing to ice bridge 12. Nipple up pump with heated fluid to Kelly hose 13. Nipple up flow cross and stripper rubber 14. Circulate warm fluid to displace diesel from well 15. Continue circulating hot water to wash ice bridge 16. Once work string moves freely through 4.5" tubing in well, open casing side to tank 3 January 25, 2019 17. Attempt to circulate through work string taking returns from inner annulus valve 18. If circulation is unsuccessful, resume circulation down work string taking returns up 4.5" tubing 19. Repeat steps 16 and 17 as necessary to thaw ice and establish circulation through the inner annulus 20. TOOH, standing back tubing Prepare and log well 21. Unset tubing hanger and TOOH, LD 4.5" tubing and demob from location 22. Move in and rig up a -line unit 23. Run in hole with a gamma and cement bond log tool 24. Log well from TD to 3331' 25. Pull out of the hole Complete and Test the AIkaid Zone of Interest (ZOI) 26. Move in and rig up PTS well testing crew 27. Trip in hole with TCP guns, ported sub, pup joint, and tubing to 8,075' 28. Run in hole with gamma and CCL to verify and correlate perforation depth 29. Pull out of hole 30. Sub out tubing as necessary to ensure perforations are at appropriate depth 31. Land tubing on hanger, run in lock -down screws a. See Attachment C: Wellbore schematic, proposed initial completion of ZOI 32. Install TIW valve in tubing hanger landing sub January 25, 2019 33. Nipple up swabbing lubricator 34. Swab well down until top of fluid is 1,509 below surface 35. ND swabbing lubricator 36. Drop bar to fire TCP guns 37. Close valve and NU flow line to tubing 38. Open valve and note pressure change after perforations 39. Open test choke and commence well testing 40. Lift well with nitrogen as needed by pumping liquid nitrogen down inner annulus Alkaid completion contingency pan Suicide squeeze If directed by Great Bear personnel, continue with this section of the procedure. If directed to plug the Alkaid ZOI, skip to the section labeled "Plug Alkaid ZOI" and proceed forward with step 41. Kill well with brine and trip out of hole with tubing 42. Nipple up lubricator and run in hole with perforating guns 43. Perforate casing at approximately 8,425' or as appropriately dictated by cement bond log 44. Pull out of hole 45. Trip in hole with tubing and cement retainer to 8,400' 46. Check tubing tally against wireline correlated depth in step 27, Verify that the additional tubing used in Step 44 is equal to the difference in wireline depths 47 Set retainer 5 January 25, 2019 48. Prior to shearing out of retainer, establish circulation down tubing, behind casing, and taking return up inner annulus. (Vote circulating pressures 49. After noting circulating pressures, pick up on tubing to shear out of cement retainer 50. Establish circulation down tubing and up inner annulus. Compare to circulating pressure in step 47 to verify a difference. 51. Sting back into retainer and circulate hole until annulus behind casing is clean 52. Pump cement per procedure. Ensure a minimum of 25 bbls (140 cubic feet) of cement placed in job 53. Placed 24 bbl (1.3X annular volume) below cement retainer. 54. Unsting from retainer, lay down 3 joints and reverse circulate 2x bottoms up 55. Trip out of hole Alkaid ZOI fracture stimulation and test 56. Trip in hole with 20' of guns, bar drop firing tool, two joints of pipe, PLS packer, on/off tool, gas lift mandrel, and 2 7/8" 6.5 Ib/ft, L-80 tubing 57. Space out tubing to place guns at 8,150' 58. Set packer and land tubing on tubing hanger. Run in lock -down screws a. See Attachment D: Wellbore Schematic, proposed completion ZOI for Frac purposes 59. Land TIW valve in tubing hanger landing joint 60. Move in and rig up Halliburton frac spread 61. Drop bar to fire perforating guns 62. Pump frac down 2 7/8" tubing per Halliburton frac procedure M January 25, 2019 a. See Attachment E: Fracture Chemical Disclosure b. See Attachment F: Anticipated fracture geometry 63. Close in, rig down and move out frac crew 64. Nipple up PTS test crew 65. Open well and flow test, gas lifting as needed down the inner annulus. Plug Alkaid ZOI 66. Shut well in 67. Circulate kill weight fluid down annulus to kill well. 68. Unset tubing hanger and unset on/off tool from packer 69. Lay Down tubing hanger and pick up joint 70. Sting back into on/off tool 71. Bullhead cement down tubing per Halliburton cement procedure, 72. Ensure a minimum of 11 barrels (63 cubic feet) of cement is pumped 73. place a minimum of 7.5 bbl (43 cubic feet) below packer to cover the volume of the casing to the perforations (64') plus 100' additional 74. Underdisplace cement by at least 3.5 bbl (20 cubic feet) 75. Unsting from packer and place a minimum of 3.5 bbl (75 linear feet) of cement on top of the packer. 76. Lay down 3 joints of tubing 77. Reverse circulate 2x bottoms up 78. Trip out of hole. 7 January 25, 2019 Shallower remedial cement work 79. Rig up a -line unit 80. Run in hole with perforating guns and perforate casing at 5,650' Note any pressure changes on Mtn 81. Pull out of hole 82. Trip in hole with tubing and cement retainer to 5,625' 83. Set retainer, shear pins and un-sting from retainer 84. Sting back into retainer 85. Establish circulation down tubing, taking returns up outer annulus 86. Place cement per cement procedure. Ensure that a minimum of 43.3 bbl of cement is pumped ' 87. Place a minimum of 41 bbl below retainer to cement 25' (1.1 bbl) of casing and 1,190' (39.9 bbl) of open hole by casing annulus. 88. Un-sting from retainer and place a minimum of 2.3 bbI (50') of cement on top of retainer 89. Lay down 3 joints and reverse circulate 2x bottoms up. 90. Trip out of hole. 91. Once cement has reached 500 psi compressive strength, bullhead diesel down outer annulus for freeze protect. West Sak Completion 92. Run in hole with Gamma and perforating guns 93. Correlate interval to log, perforate West Sak interval at approximately 5,390' 11 January 25, 2019 94. Note any pressure changes on well. Bleed off pressure or kill well as needed 95. Trip in hole with tubing and seat nipple to 5,350' a. See Attachment G: Wellbore Schematic proposed West Sak completion 96. Land tubing on hanger and run in lock -down screws 97. Nipple up TIW valve and test crew to tubing 98. Begin well test, lifting well using nitrogen as needed 99. Shut in well, kill well if needed West Sak Plugging 100. Unset hanger and trip out of hole 101. Trip in hole with cement retainer on tubing to 5,300' 102. Set retainer, shear pin and un-sting, sting back into retainer 103. Pump cement per cementing procedure. 104. Ensure that a minimum of 9.3 bbl (52 cubic feet) of cement is pumped 105. Ensure that a minimum of 7 (39 cubic feet) of cement is placed below the retainer to cover the 50' to the perforations with 100' of extra volume 106. Ensure that a minimum of 2.3 bbl (13 cubic feet) remains in tubing 107. Unsting from retainer and place remaining cement on top of cement retainer 108. Lay down three joints 109. Reverse circulate 2x bottoms up 110. Trip out of hole we January 25, 2019 Ugnu Completion and Test 111. Rig up eline 112. Run in hole with Gamma guns and perforate 6 different sand lobes. Correlate perforations to logs with gamma. Anticipated perforations are at 4,880, 4,830, 4,800, 4,720, 4,670, and 4,600 113. Note pressure changes on the well 114. Bleed down or kill well as needed 115. Trip in hole with PLS packer, on/off tool, gas lift mandrel, and 2 7/8" 6.5 lb/ft, L-80 tubing 116. Space tubing to place packer at 4,550' 117. Set packer and land tubing on tubing hanger, run in lockdown screws a. See Attachment H: Wellbore Schematic proposed Ugnu completion 118. Set backpressure value in tubing hanger 119. Nipple down BOP's, nipple up tree 120. Pressure test tree 121. Rig down and move out AAOS rig 111 122. Nipple up PTS test skid to tree 123. Production test the Ugnu formation, lift with nitrogen down the annulus as needed Plug well 124. Shut in well Iff January 25, 2019 125. Nipple up cement crew to outer annulus. 126. Bullhead squeeze outer annulus per cement procedure. Ensure that a minimum of 145 bbl of cement is pumped to cement 3,331' of annulus plus 10% extra 127. Nipple down cement crew from outer annulus 128. Nipple up cement crew to tubing, ensure a quick method for switching to pumping down annulus 129. Pump bullhead cement squeeze per procedure down tubing 130. Ensure that a minimum of 7 (39 cubic feet) of cement is placed below the packer to cover the 50' to the perforations with 100' of extra volume 131. Switch cement setup to pump down anulus and take returns through tubing 132. Reverse circulate water down casing, through gas lift valve, and up tubing 133. Circulate cement down inner annulus taking returns up tubing 134. Ensure cement is circulated to surface a. See Attachment I: Wellbore Schematic proposed plugged configuration 135. Rig down and move out cement crew 136. Cut all tubulars 6' below grade 137. Weld identification cap on remaining stub 138. Remove cellar and backfill 139. Rig down and move out all equipment January 25, 2019 IE January 25, 2019 Attachment A: Wellhead drawings 13 GE Oil & Gas January 25, 2019 Attachment B: Alkaid current configuration wellbore schematic 14 Alkaid #1 Wellbore schematic, well conditoin as of January 2019 r I I r r 76.5 bbi diesel ; I Ugnu 4,575' - 5,050' West Sak 5,370' - 5,460' Alkaid Zone of Interest 7,900' - 8,450' 31.5 bbl Diesel —750' I 9 6 brine Conductor I Surface Hole Bit Size 12 3 4 Casing Depth 3,331 Casing Size 10 3 4 in E-3331' Weight: 45.5 Ib/ft Grade: L-80 Cemented head to toe I Tubing Depth 1,233 Tubing Size 4.5" TOC 5,750 i Production Hole Bit Size Casing Depth Casing Size Weight: Grade: i Shoe Track, 8,450' 8,595' TD 95 8 8,595 75 8 29.7 L-80 in Ib/ft 0 January 25, 2019 Attachment C: Wellbore schematic, proposed initial completion of ZOI 15 Alkaid #1 Wellbore schematic, proposed initial completion of ZOI I I 76.5 bbl diesel 1 Ugnu 4,575' - 5,050' West Sak ; 5,370' - 5,460' �I t f Alkaid Zone of Interest 7,900' - 8,450' Conductor I Surface Hole Bit Size 12 3 4 Casing Depth 3,331 Casing Size 10 3/4 in U3331' Weight: 45.5 Ib/ft Grade: L-80 Cemented head to toe I I I Production Hole Bit Size 9 5 8 Casing Depth 8,595 Casing Size 7 5/8 in Weight: 29.7 Ib/ft Grade: L-80 I �TOC 5,750 ) Shoe Track, 8,450' 8,595' TD Tubing Depth 8,075 Tubing Size 2 7/8" Tubing Weight 6.5 Ib/ft Tubing Grade L-80 Perforations TCP, 5'-10' Depth EDT (8,075) January 25, 2019 Attachment D: Wellbore Schematic, proposed completion ZOI for Frac purposes In Alkaid #1 Wellbore schematic, proposed compleiton Z01 for Frac purposes Conductor I I Surface Hole Bit Size 12 3 4 I Casing Depth 3,331 I Casing Size 10 3/4 in -3331' Weight: 45.5 ib/ft 7&5 bbl diesel Grade: L-80 I e I Cemented head to toe , Ugnu 4,575' - 5,050' , 1 I , Production Hole Bit Size 9 5 8 West Sak Casing Depth 8,595 5,370' - 5,460' � I I Casing Size 7 5/8 in I Weight: 29.7 Ib/ft Grade: L-80 i JOC 5,750 t � Tubing Depth 8,100 Tubing Size 2 7/8" Tubing Weight 6.5 Ib/ft Tubing Grade L-80 Frac Perforations 8150 Alkaid Zone of Interest 7,900' - 8,450' I Cement Squeeze 8,075-8,425 Cement Retainer 8,400 Shoe Track, 9,450' 8,595' TD January 25, 2019 Attachment E: Fracture Chemical Disclosure N �OO N o oxE aE o x E loxiE 2 Ci m Z O o 0 0 s x x S S m o � S n N x Y O E N W g� A zzz z z z z z I A E-= oizan a m a v o a o a O d n m m N lw G C m O O c c G O �s c m n m a m m� m€ m€ ro E € € s� y€ r r r W5 dco� 9 m m m m m m m m m m m �j F 4dp u Yo G O m � w d a m m m m m m m m m m m m m E a m '- C C y y�yJ °9' xmt� SY m E Q m 8 2 u U U 5i c� G p x N 9 ii C ui/ d m m n LL a 3 'w m Z x m d a [�7 LL C �Y gE C n a 7c g` .2 1.1.1.1 . n$ R m o x x x xxx x x x x x S x o.. � C S `-' o� - brow dJJowy(W oy��m � 0wwm Faww z— c 332�a d�� a x Y.m�000o�2Ooaoo�m v��m r�3mur LL 0, C 3 fy.7 LL January 25, 2019 Attachment F: Anticipated fracture geometry 18 r s R oLA � ~ Ln # w aj � « E M U Mu to m £ toE o . ) tA ' m U o -D / 2 E & 4L 7 _ z f'= 2� g00 q 2&2 § E @ aj k 2 � b Ln � -0 § S C E o w @ 5 NOOO \c � � cu ^ 2 § c Z CL f CL c L ƒ E_� @ § en C E T 'n 0 ¥ CO 2 § � u © o J 2 # n :L� 2 N � ¥ 2%f� � Ln J § E kin tvi ƒ 2 t 4- k @ _ 0 % E2 \k LA m / E 2 u 2 R m E n o . January 25, 2019 Attachment G: Wellbore Schematic proposed West Sak completion Ice Alkaid #1 Wellbore schematic ZOI plugged, remedial cement up hole complete West Sak compelete I � 76 5 bbl diesel ; I i 4,575' - 5,050' 5,370' - 5,460' Alkaid Zone of Interest 7,900' - 8,450' Conductor i Surface Hole Bit Size 12 3 4 Casing Depth 3,331 Casing Size 10 3/4 �3331' Weight: 45.5 Grade: L-80 I Cemented head to toe I TOC 5,750 in Ib/ft Tubing Depth 5,350 Tubing Size 2 7/8" Tubing Weight 6.5 Ib/ft Tubing Grade L-80 Production Hole Bit Size 9 5 8 i .'Shoe Track, 8,450' 8,595' TD Casing Depth 8,595 Casing Size 7 5/8 in Weight: 29.7 Ib/ft Grade: L-80 Plugging cement 8,000-9,150 Cement Squeeze 8,075-8,425 Cement Retainer 8,400 January 25, 2019 Attachment H: Wellbore Schematic proposed Ugnu completion 20 4 Alkaid #1 Wellbore schematic ZOI plugged, West Sak plugged Ugnu compelete f i 76.5 bbl diesel f 4 t _ Ugnu 4,575' - 5,050' i West Sak 5,370' - 5,460-1 Alkaid Zone of Interest 7,900' - 8,450' 0 �Mm M'd Conductor Surface Hole Bit Size 12 3 4 Casing Depth 3,331 Casing Size 10 3/4 in -3331' Weight. 45.5 Ib/ft Grade: L-80 I Cemented head to toe Tubing Depth 4,550 Tubing Size 2 7/8" Tubing Weight 6.5 Ib/ft Tubing Grade L-80 ITOC 5,750 i Production Hole Bit Size Casing Depth j' i Casing Size Weight: I Grade: i 95 8 8,595 7 5/8 in 29.7 Ib/ft L-80 Plugging cement 8,000-8,150 Cement Squeeze 8,075-8,425 Cement Retainer 8,400 January 25, 2019 Attachment I: Wellbore Schematic proposed plugged configuration a Ugnu 4,575' - 5,050' West Sak 5,370' - 5,460' Alkaid Zone of Interest 7,900' - 8,450' Alkaid #1 Wellbore schematic Proposed plugged configuration :onductor Surface Hole Bit Size 12 3 4 Casing Depth 3,331 Casing Size 10 3/4 in 1' Weight: 45.5 Ib/ft Grade• L-on Cemented head to toe Tubing Depth 4,550 Tubing Size 2 7/8" Tubing Weight 6.5 Ib/ft Tubing Grade L-80 F50 Production Hole Bit Size 9 5 8 Casing Depth 8,595 Casing Size 7 5/8 in Weight: 29.7 Ib/ft Grade: L-80 Plugging cement 8,000-8,130 Cement Squeeze 8,075-8,425 Cement Retainer 8,400 ack, 8,450' 8,595' TD January 25, 2019 Attachment J: Maximum anticipated surface pressure calculation 22 January 25, 2019 Maximum anticipated surface pressure Depth of deepest interval: 7900' Mud weight equivalent pore pressure gradient of interval: 9 ppg Anticipated pore pressure of interval = Mud weight equivalent * .052 * Depth of interval Anticipated pore pressure of interval 9 ppg * .052 psi/ft/ppg * 7900 Anticipated pore pressure = 3,697 psi Anticipated pressure due to gas gradient = 0.1* Depth of Interval Anticipated pressure due to gas gradient = 0.1* 7900 790 Maximum Anticipated Surface Pressure = Anticipated pore pressure — Anticipated pressure due to gas gradient Maximum Anticipated Surface Pressure 3,697 — 790 Maximum Anticipated Surface Pressure = 2,907 psi 23