FOR DIVISION USE ONLY
Forms
Bond OGD114 OGD121
NATURAL RESOURCES AGENCY OF CALIFORNIA
DEPARTMENT OF CONSERVATION
DIVISION OF OIL, GAS, AND GEOTHERMAL RESOURCES
NOTICE OF INTENTION TO ABANDON / RE-ABANDON WELL Detailed instructions can be found at: www.conservation.ca.gov/dog
In compliance with Section 3229, Division 3, Public Resources Code, notice is hereby given that it is our intention to abandon / re-abandon well Standard Sesnon 25 , API No. 037-00776 , (Check one)
Sec. 28 , T. 3N , R. 16W , S.B. B.&M., Aliso Canyon Field, Los Angeles County.
The complete casing record of the well (present hole), including plugs and perforations, is as follows: (Attach wellbore schematics diagram also.) See attached wellbore schematic
The total depth is: 8749 feet. The effective depth is: 7580 feet.
Present completion zone(s): N/A plugged back . Present zone pressure: N/A psi. (Name)
Oil or gas shows: See attached program feet. Depth to base of fresh water: 800 feet.
(Name and depth)
Top of uppermost hydrocarbon zone (which may be behind unperforated casing): Pliocene Gas Sand: 2,703' feet.
(Depth of interval)
Is this a critical well as defined in the California Code of Regulations, Title 14, Section 1720(a) (see next page)? Yes No
The proposed work is as follows: (A complete program is preferred and may be attached.)
See attached program
The Division must be notified immediately of changes to the proposed operations. Failure to provide a true and accurate representation of the well and proposed operations may cause rescission of the permit. Name of Operator
Southern California Gas Company Address
P. O. Box 2300 City/State
Chatsworth Zip Code
91313-2300 Name of Person Filing Notice
Thomas McMahon Telephone Number:
562.806.4429 Signature
Thomas McMahon Date
3/30/2018
Individual to contact for technical questions: Telephone Number: E-Mail Address:
Ella Lein 818. 700. 3890 [email protected]
This notice must be filed, and approval given, before plugging and abandonment operations begin. If operations have not commenced within one year of the Division’s receipt of the notice, this notice will be considered cancelled.
OG108 (1/09)
CRITICAL WELL DEFINITION
As defined in the California Code of Regulations, Title 14, Section 1720 (a), “Critical well” means a well within:
(1) 300 feet of the following: (A) Any building intended for human occupancy that is not necessary to the operation of the well; or (B) Any airport runway.
(2) 100 feet of the following: (A) Any dedicated public street, highway or the nearest rail of an operating railway that is in general use; (B) Any navigable body of water or watercourse perennially covered by water; (C) Any public recreational facility such as a golf course, amusement park, picnic ground, campground or any
other area of periodic high-density population; or (D) Any officially recognized wildlife preserve.
This form may be printed from the DOGGR website at www.conservation.ca.gov/dog/
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 1 of 15
Southern California Gas Company Standard Sesnon 25
Blade’s Phase 3A Contingency Part 2 and Well Abandonment Operations Procedure
Aliso Canyon
March 30, 2018 Well Data: API #: 037-00776 KB to GL: 6’ above GL at 2927’ MD: 8,749’ TVD: 8,733’ PBMD: 7,555’ Nature of Plug Back: CIBP and Cement Surface Location: Sec. 28, T 3N, R 16W Estimated Bottom-hole Static Temp: 150 F Estimated Formation Fracture Gradient: 0.556 psi/ft
Casing and Tubing Data:
Surface Casing: 11-3/4” 42 ppf H-40 Cemented at 990’
Production Casing: 7” 0’ – 939’ 29 ppf N-80 (tieback casing) 939’ – 2,398’ 23 ppf J-55 2,398’ – 6,308’ 23 ppf N-80 6,308’ – 8,282’ 26 ppf N-80 8,282’ – 8,585’ 29 ppf N-80
Cemented with 600 sacks, ETOC at 7,000’, WSO perforations at 8,474’ and 8,583’, TOC in 7” casing at 7,590’
Production Liner: 5-1/2” 20 ppf J-55; 8,559’ – 8,749’ – Plugged Back (Intercepted the well at 8,612’ via the Porter 39A relief well)
Production Tubing: 2-7/8” 6.5 ppf J-55; 7,555’ – 8,496’, Tubing CIBP at 7,572’, Cement from 7,580’ – 8,496’
Kill String:
Kill string 3-1/2” 9.3 ppf N-80 at approximately 7,524’
Wellhead:
13-5/8” 5M Casing Head, 11” 5M Tubing Head (Diverter with 6” diverter line and 13-5/8” 5M BOP on the tubing head)
Geologic Markers:
a. BFW: 800’ (+/-) MD b. Pliocene Gas Sand: 2,703’ MD c. A1 (Aliso Sand): 4,650’ MD d. A36 (Aliso Sand): 5,527’ MD e. Upper Porter: 5,820’ MD f. Lower Porter: 6,245’ MD g. Upper Del Aliso 1: 6,566’ MD h. Upper Del Aliso 2: 6,871’ MD
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 2 of 15
i. Middle Del Aliso: 7,350’ MD j. Lower Del Aliso: 7,588’ MD k. MP: 8,182’ MD l. S1: 8,395’ MD m. S2: 8,434’ MD n. S4: 8,492’ MD o. S6: 8,509’ MD p. S8: 8,600’ MD q. S10: 8,628’ MD r. S12: 8,702’ MD s. S14: 8,748’ MD Perforations:
Plugged back with cement Slotted liner, 8,592’ – 8,748’ (120 Mesh x 2” slots 6” centers) Perforated with 4 jspf at 8,510 – 8,538’, 8,542’ – 8,559’
Current Status: Idle, rig on standby. The work is suspended pending Supplemental NOI approval.
Permit Status: Pending
Work performed to date: As per the Supplementary Permit issued October 2, 2017, including recovery of the parted 7” production casing to 939’, running a suite of logs to evaluate the 11-3/4” casing, running 7” tieback casing from 939’ to surface and running a suite of logs to evaluate the 7” casing.
Table of Critical Zones
Critical Zones Depth (ft) Annulus Est. Bot. of Annulus
Squeeze (ft) Est. Top of Annulus
Squeeze (ft)
Casing Plug Tag Depth or
Higher (ft)
Base Fresh Water * (See SCG attachment for BFW depth justification)
800 Squeeze 800 650 700
Pliocene Gas Sand 2,703 Squeeze 2,703 2,203 2,603
A1 (Top Aliso Sand) 4,650 Squeeze 4,654 4,504 4,554
A36 (Deepest Aliso Sand) 5,527 Squeeze 5,527 5,377 5,427
Upper Porter 5,820 Squeeze 5,820 5,670 5,720
Lower Porter 6,245 Squeeze 6,245 6,095 6,145
Upper Del Aliso 1 6,566 Squeeze 6,566 6,416 6,466
Middle Del Aliso 7,350 Cemented
Lower Del Aliso 7,588 Cemented
Miocene/Pliocene Unconf. 8,182 Cemented
S1 Sesnon 8,395 Cemented
Project Notes:
1. BOPE requirements in Gas Company Standard 224.05 shall be fully implemented at all
times.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 3 of 15
2. The storage reservoir pressures shall be monitored during the workover with a minimum
of 300 psig overbalance for well control fluids.
3. Prepare the location by removing all relevant landscaping/lighting fixtures as well as
surface piping and electrical components as required.
4. DOGGR permit must be posted on site. Notify DOGGR as required for BOPE testing
prior to commencing downhole operations as stated on permit. DOGGR Ventura District
office (805)-654-4761. If a permit has not been issued, contact DOGGR prior to rigging
up on the well for verbal approval to rig up.
SS-25 Phase 3A Contingency Part 2 Summary Steps
1. Ensign Rig 540 is rigged up over the well.
2. A diverter with a 6” diverter line and Class III 5M BOPE is currently nippled up on the 11”
5M tubing head. Pressure test the BOPE and function test the diverter. Function test the
diverter weekly and record the function test on the daily report.
a. All tests are to be charted and witnessed by a DOGGR representative.
b. Perform a 300 psig low pressure test on the annular preventer, blind rams and pipe
rams for 20 minutes. Pressure test all lines and connections to 300 psig.
c. Pressure test the Class III 5M annular preventer to 3,500 psig for 20 minutes. Test
the blind and pipe rams to 5,000 psig for 20 minutes. Pressure test all lines and
connections to 5,000 psig.
d. Remove test plug from the tubing hanger.
3. POH with the tubing workstring.
4. RIH with noise and temperature logs to 1500’.
5. Pump fluid down the 11-3/4” x 7” annulus and monitor noise and temperature logs to
determine a fluid flow path near the 11-3/4” casing shoe if one exists.
6. Run a gyro survey to 1,500’ in the 7” casing at 10’ intervals.
7. RIH with a 5” OD x 4” ID wash shoe and 5” washpipe to clean out between the tubing
and casing from 7555’ and 7590’. Make a diligent effort to clean out to the TOC in the
annulus at approximately 7590’.
a. Contact DOGGR to witness tagging the 7” x 2-7/8” annulus plug.
b. If unable to make progress, stop and contact DOGGR for authorization to proceed
with the work.
8. RIH with a joint of 5” washpipe on the workstring to get over the tubing stub and balance
a 200’ cement plug (7.7 bbl) in the 7” x 2-7/8” tubing annulus and 7” casing.
a. Plug #1, 7590’ to 7390’
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 4 of 15
b. Type III Cement Intermediate Blend
Intermediate Blend Composition Properties
Type III Cement Yield 1.75 cu ft/sack35% SSA‐1 Silica Flour Water 7.92 gal/sack0.5% Halad 322 Fluid Loss Control Additive Density 14.8 ppg0.3% CFR‐3 Friction Reducer Compressive Strength 2045 psi in 8 hours Permeability 0.0018 mD
9. Tag top of plug. Tag must be witnessed by DOGGR.
10. RU eline. RIH and take 7” casing annulus fluid samples and annulus pressures using the
Schlumberger Cased Hole Dynamics Tester (CHDT) at the proposed depths shown in
the table below. Correlate to the Schlumberger Isolation Scanner Cement Evaluation log
run on December 4, 2017. RD eline.
a. The CHDT holes will be plugged and pressure tested to 1000 psi using the CHDT
tool after the samples are taken.
b. If the plug fails to pressure test, the situation will be evaluated. If the leak is deemed
a safety or operational risk, the hole will be squeeze cemented and pressure tested
to 1000 psi. Notify DOGGR if a pressure test fails.
c. Compile the pressure charts, including the pressure tests for submission to DOGGR.
Count CHDT Depths
(ft)
Count CHDT Depths
(ft)
Count CHDT Depths
(ft)
1 975 10 1,218 19 3,659
2 994 11 1,552 20 4,121
3 1,006 12 1,664 21 4,186
4 1,046 13 1,680 22 4,285
5 1,054 14 1,918 23 4,810
6 1,084 15 2,031 24 5,980
7 1,100 16 2,295 25 6,240
8 1,116 17 2,560 26 6,716
9 1,168 18 2,706 ‐ ‐
11. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. Correlate to the
Schlumberger Isolation Scanner Cement Evaluation log run on December 4, 2017. RD
eline.
a. MSCT 7337’
b. MSCT 7126’
12. RIH with the workstring to the TOC (approximately 7390’) and balance a 500’ cement
plug (19.1 bbl Intermediate Blend) in the 7” casing.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 5 of 15
a. Plug #2, 7390’ to 6890’
13. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. Correlate to the
Schlumberger Isolation Scanner Cement Evaluation log run on December 4, 2017. RD
eline.
a. MSCT 6721’
14. RIH with the workstring to the TOC, approximately 6890’ and balance a 274’ cement
plug (10.5 bbl Intermediate Blend) in the 7” casing.
a. Plug #3, 6890’ to 6616’
15. Tag the TOC at 6621’ or above. Contact DOGGR to witness the tag.
16. Confirm the casing integrity.
a. Pressure test the casing to 500 psi for 30 minutes. Record the test. Notify DOGGR to
witness the pressure test.
17. RU eline. RIH and perforate to squeeze the UDA-1 6566’ – 6576’ using a 10’ 4 spf 90°
phase gun. RD eline.
18. Criteria for Injection Rate.
a. Establish an injection rate based on a surface pressure not to exceed a 0.556 psi/ft
gradient at the perforations.
b. If an injection rate of >3 bpm is established, pump a mud push spacer ahead of the
cement and squeeze the zone. Contact DOGGR to witness squeeze jobs.
c. If the injection rate is <3 bpm, contact DOGGR and discuss the options prior to
proceeding. Options include re-perforate, balance a cement plug and apply squeeze
pressure, etc.
19. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 19.1 bbl (499 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 6616’ to 6117’. PU above the cement. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Contact DOGGR to witness the squeeze job.
b. Squeeze UDA-1, 6566’ to 6416’, 150’ length. Volume 9.3 bbl (100’ in the annulus +
50% excess)
c. Estimated cement plug inside casing 6616’ – 6360’.
20. Tag the TOC at 6466’ or above. Contact DOGGR to witness the tag.
21. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 6 of 15
a. MSCT 6260’
22. RU eline. RIH and perforate to squeeze the LP 6245’ – 6255’ using a 10’ 4 spf 90°
phase gun. RD eline.
23. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 19.7 bbl (500 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 6360’ to 5860’. PU above the cement. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Contact DOGGR to witness the squeeze job.
b. Squeeze LP, 6245’ to 6095’, 150’ length. Volume 9.3 bbl (100’ in the annulus + 50%
excess)
c. Estimated cement plug inside casing 6360’ – 6095’.
24. Tag the TOC at 6145’ or above. Contact DOGGR to witness the tag.
25. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. Correlate to the
Schlumberger Isolation Scanner Cement Evaluation log run on December 4, 2017. RD
eline.
a. MSCT 6020’
26. RIH with the workstring to the TOC (approximately 6095’) and balance a 225’ cement
plug (8.9 bbl Intermediate Blend) in the 7” casing.
a. Plug #4, 6095’ to 5870’
27. Tag the TOC at 5920’ or above. Contact DOGGR to witness the tag.
28. RU eline. RIH and perforate to squeeze the UP 5820’ – 5830’ using a 10’ 4 spf 90°
phase gun. RD eline.
29. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 19.9 bbl (505 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 5870’ to 5365’. PU above the cement. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Contact DOGGR to witness squeeze jobs.
b. Squeeze UP, 5820’ to 5670’, 150’ length. Volume 9.3 bbl (100’ in the annulus + 50%
excess)
c. Estimated cement plug inside casing 5870’ – 5600’.
30. Tag the TOC at 5720’ or above. Contact DOGGR to witness the tag.
31. RU eline. RIH and perforate to squeeze the A-36 5527’ – 5537’ using a 10’ 4 spf 90°
phase gun. RD eline.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 7 of 15
32. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 18.1 bbl (460 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 5600’ to 5140’. PU above the cement. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Contact DOGGR to witness squeeze jobs.
b. Squeeze A-36, 5527’ to 5377’, 150’ length. Volume 9.3 bbl (100’ in the annulus +
50% excess)
c. Estimated cement plug inside casing 5600’ – 5377’.
33. Tag the TOC at 5427’ or above. Contact DOGGR to witness the tag.
34. RIH with the workstring to the TOC (approximately 5377’) and balance a 300’ cement
plug (11.8 bbl Intermediate Blend) in the 7” casing.
a. Plug #5, 5377’ to 5077’
35. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
a. MSCT 4791’
36. RIH with the workstring to the TOC (approximately 5077’) and balance a 373’ cement
plug (14.7 bbl Intermediate Blend) in the 7” casing.
a. Plug #6, 5077’ to 4704’
37. Tag the TOC at 4691’ or above. Contact DOGGR to witness the tag.
38. RU eline. RIH and perforate to squeeze the A-1 4654’ – 4664’ using a 10’ 4 spf 90°
phase gun. RD eline.
39. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 17.3 bbl (439 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 4704’ to 4265’. PU above the cement. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Contact DOGGR to witness squeeze jobs.
b. Squeeze A-1, 4654’ to 4504’, 150’ length. Volume 9.3 bbl (100’ in the annulus + 50%
excess)
c. Estimated cement plug inside casing 4704’ – 4500’.
40. Tag the TOC at 4554’ or above. Contact DOGGR to witness the tag.
41. Confirm wellbore integrity.
a. Pressure test the casing to 500 psi for 30 minutes. Record the test and notify
DOGGR to witness the test.
b. Check for gas using a gas monitor after the well has been shut in overnight.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 8 of 15
42. RIH and set a cement retainer or CIBP above the TOC.
43. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
a. MSCT 4110’
b. MSCT 3666’
44. RIH with the workstring to the TOC (approximately 4500’) and balance a 500’ cement
plug (19.7 bbl Intermediate Blend) in the 7” casing.
a. Plug #7, 4500’ to 4000’
45. RIH with the workstring to the TOC (approximately 4000’) and balance a 500’ cement
plug (19.7 bbl Intermediate Blend) in the 7” casing.
a. Plug #8, 4000’ to 3500’
46. Tag the TOC at 3566’ or above. Contact DOGGR to witness the tag.
47. RU eline. RIH and perforate to squeeze the 10-5/8” x 7” annulus 3450’ – 3460’ using a
10’ 4 spf 90° phase gun. RD eline.
48. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 20.3 bbl (516 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 3500’ to 2984’. PU above the cement. Attempt to
squeeze 200 linear feet of cement into the annulus.
a. Squeeze Annulus, 3450’ to 3250’, 200’ length. Volume 12.4 bbl (133’ in the annulus
+ 50% excess)
b. Estimated cement plug inside casing 3500’ – 3300’.
49. RIH with the workstring to the TOC (approximately 3300’) and balance a 500’ cement
plug (19.7 bbl Intermediate Blend) in the 7” casing.
a. Plug #9, 3300’ to 2800’
50. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
a. MSCT 2713’
51. RU eline. RIH and perforate to squeeze the PGS 2703’ – 2713’ using a 10’ 4 spf 90°
phase gun. RD eline.
52. Establish the injection rate and maximum surface pressure according to the Criteria for
Injection Rate. Lay a 35.4 bbl (899 linear feet in the casing Intermediate Blend) cement
plug from the TOC, approximately 2800’ to 1901’. PU above the cement. Attempt to
squeeze 500 linear feet of cement into the annulus. Leave the TOC in the casing at
approximately 2690’.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 9 of 15
a. Contact DOGGR to witness squeeze jobs.
b. Squeeze PGS, 2703’ to 2203’, 500’ length. Volume 31.0 bbl (333’ in the annulus +
50% excess)
c. Estimated cement plug in the casing 2800’ – 2690’.
d. If the PGS was squeezed, drill out to 2690’ in preparation for the CBL.
53. If the PGS was squeezed, WOC for at least 48 hours. Run a CBL while holding 500 psi
on the casing, from 2690’ to 2000’ to confirm cement integrity behind the casing. Consult
and review the CBL with DOGGR prior to proceeding with the next step.
54. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
a. MSCT 2553’
b. MSCT 2372’
c. MSCT 2289’
d. MSCT 2037’
e. MSCT 1925’
55. RIH with the workstring to the TOC (approximately 2690’) and balance a 500’ cement
plug (19.7 bbl Intermediate Blend) in the 7” casing.
a. Contact DOGGR to witness the cement plug placement.
b. Plug #10, 2690’ to 2190’
56. RIH with the workstring to the TOC (approximately 2190’) and balance a 500’ cement
plug (19.7 bbl Intermediate Blend) in the 7” casing.
a. Plug #11, 2190’ to 1690’
57. Tag the TOC at 1825’ or above. Contact DOGGR to witness the tag.
58. RU eline. RIH and take 7” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) in the following order at the following depths. RD eline.
a. MSCT 1625’
b. MSCT 1564’
c. MSCT 1140’
d. MSCT 1092’
e. MSCT 1035’
59. RIH with the workstring to the TOC (approximately 1690’) and balance a 420’ cement
plug (16.5 bbl Shallow Blend) in the 7” casing.
a. Plug #12, 1690’ to 1270’
b. Type III Cement Shallow Blend
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 10 of 15
Shallow Blend Composition Properties
Type III Cement Yield 1.36 cu ft/sack0.5% Halad 322 Fluid Loss Control Additive Water 6.46 gal/sack0.4% Halad 344 Dispersant Density 14.8 ppg2.0% CaCl2 Compressive Strength 1062 psi in 8 hours Permeability 0.00025 mD
60. RIH with the workstring to the TOC (approximately 1270’) and balance a 230’ cement
plug (9.1 bbl Shallow Blend) in the 7” casing. Contact DOGGR to witness the cement
plug placement.
a. Plug #13, 1270’ to 1040’
61. Tag the TOC at approximately 1040’. Contact DOGGR to witness the tag.
62. Dress the TOC to 1040’ if required.
63. RIH and cut the 7” casing at a target depth of 1024’ and no deeper than 1027’. POH and
LD cutter. Nipple down the BOPE and diverter. ND the tubing head. Pick up the casing
with a spear. Remove the casing slips. Set the casing down and release the spear.
64. NU BOPE and the diverter on the 13-5/8” 5M casing head. Pressure test the BOPE
breaks and function test the diverter. Notify DOGGR to inspect the BOPE.
65. Pick up the casing with a spear. POH and lay down the 7” casing. The 7” casing includes
the temporary tieback casing and approximately 85’ of original 7” casing. Handle and lay
down the original casing according to the Blade Tubular Handling Protocol document.
66. RU eline. RIH with open hole caliper and log from the 11-3/4” shoe to the 7” casing stub.
Circulate and condition the fluid if required. RIH with a FMI tool and log from the 11-3/4”
shoe to the 7” casing stub.
67. RIH with a 11-3/4” casing scraper. Prepare the 11-3/4” casing for logs. POH with casing
scraper.
68. Run 11-3/4” casing logs. Refer to the Proposed 11-3/4” Logs.
Proposed 11-3/4” Logs
Log Description Purpose Provider Tool Name Abbreviation
Noise – Temperature Evaluate possible flow paths near the 11‐3/4” casing shoe
TBD Noise
Temperature
Open hole logs Evaluate open hole ID and borehole image
SLB Caliper
Formation Micro‐Imager
Caliper FMI
Junk Basket, Gauge Ring, Gamma Ray, Casing Collar Locator
Determine if there are any ID restrictions in the 11‐3/4” casing
Baker ‐‐ JB‐
GR/GR/CCL
Mechanical Caliper 11‐3/4" ID measurements, deformation, corrosion indications
Baker ICAL Multi‐
Finger Caliper ICAL
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 11 of 15
Log Description Purpose Provider Tool Name Abbreviation
Annulus Evaluation Evaluate Cement Quality Baker Integrity
Explorer Cement Evaluation
IntEX CBL
Annulus evaluation 11‐3/4" Casing condition
Solid‐liquid‐gas map of annulus material, hydraulic communication map, acoustic impedance, flexural attenuation, rugosity image, casing thickness image, internal radius image
SLB
Isolation Scanner
Ultrasonic
Casing Imager
IBC
UCI
Formation evaluation Lithology type, water, hydrocarbon identification
SLB Pulsed Neutron
Extreme LithoScanner
PULSAR NEXT
Active corrosion detection
Identify anodic/cathodic cells indicating active corrosion
SLB Corrosion and Protection
Evaluation Tool CPET
Downhole camera Visual inspection of the 11‐3/4" casing ID for defects and anomalies
EV EV Downhole Video Camera
MK2
69. Evaluate the log data to determine if additional squeeze cement jobs are necessary to
isolate the fresh water. Contact DOGGR to review and approve any proposed changes
based on log evaluation.
70. RIH and take 11-3/4” casing annulus fluid samples using the Schlumberger Cased Hole
Dynamics Tester (CHDT) at various depths (depths to be determined by log evaluation).
71. RIH and take 11-3/4” casing samples using the Schlumberger Mechanical Sidewall
Coring Tool (MSCT) at various depths (depths to be determined by log evaluation).
72. Run a gyro survey in the 11-3/4” casing at 10’ intervals.
73. Displace the fluid to clear fluid for a video camera run.
74. Run a video camera in the 11-3/4” casing.
75. RIH and displace the clear fluid with 9 ppg fluid.
76. Run 7” casing tieback and connect to the casing stub at approximately 1024’.
77. Cut the casing between 985’ and 940’. The target cut depth is 980’. Plugs assume a cut
depth at 980’.
78. POH and lay down the casing.
79. RIH with the workstring to the TOC in the 7” casing (approximately 1040’) and balance a
34.6 bbl (290 linear feet of Shallow Blend) cement plug inside the 11-3/4” casing to
isolate the 11-3/4” shoe.
a. Estimated cement plug inside the 7” casing 1040’ to 980’ (2.4 bbl)
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 12 of 15
b. Estimated cement in the 16” x 11-3/4” annulus 990’ to 840’ (17.2 bbl, 100’ in the
annulus + 50% excess)
c. Estimated cement in the 11-3/4” x 7” annulus 990’ to 980’ (0.7 bbl)
d. Estimated cement in the 11-3/4” casing 980’ to 860’ (14.3 bbl)
80. Tag top of plug 100’ above the casing stub or higher at approximately 880’. Tag must be
witnessed by DOGGR.
81. RIH and set an 11-3/4” cement retainer at the top of cement, approximately 860’.
82. RIH with the workstring to the cement retainer (approximately 860’) and balance a 6.0
bbl (50 linear feet of Shallow Blend) cement plug in the 11-3/4” casing.
a. Plug #14, 860’ to 810’
83. Evaluate the 11-3/4” cement at the BFW at approximately 800’. If no cement, RIH and
perforate to squeeze the BFW 800’ – 810’ using a 10’ 4 spf 90° phase gun. RD eline.
84. RIH and set a packer at approximately 760’ and establish the injection rate and
maximum surface pressure according to the Criteria for Injection Rate. Mix and pump
20.8 bbl of Shallow Blend cement. Squeeze 17.2 bbl from 800’ to 650’. Attempt to
squeeze 150 linear feet of cement into the annulus.
a. Squeeze BFW, 800’ to 650’, 150’ length in the 16” x 11-3/4” annulus. Volume 17.2
bbl (100’ in the annulus + 50% excess)
b. Estimated cement plug inside the casing 810’ to 780’ (3.6 bbl).
85. RIH with the workstring to the TOC (approximately 780’) and balance a 23.9 bbl (200
linear feet of Shallow Blend) cement plug in the 11-3/4” casing.
a. Plug #15, 780’ to 580’
86. Tag the TOC at 700’ or above. Contact DOGGR to witness the tag.
87. Run and set a cement retainer at the TOC at approximately 580’.
88. RIH with the workstring to the TOC (approximately 580’) and balance a 200’ cement plug
(23.9 bbl Shallow Blend) in the 11-3/4” casing.
a. Plug #16, 580’ to 380’
89. RIH with the workstring to the TOC (approximately 380’) and balance a 200’ cement plug
(23.9 bbl Shallow Blend) in the 11-3/4” casing.
a. Plug #17, 360’ to 180’
90. RIH with the workstring to the TOC (approximately 180’) and balance a 165’ cement plug
(19.7 bbl Shallow Blend) in the 11-3/4” casing.
a. Plug #18, 180’ to 15’
91. ND BOPE.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 13 of 15
92. Cut the 11-3/4” casing below the casing head and release the casing head to Blade for
RCA evaluation. Weld on a riser to extend the casing if necessary to meet the
requirement of the top of casing cut off 5’ to 10’ below ground level.
93. Cut the casing 5’ to 10’ below ground level. Contact DOGGR to witness.
94. Perform bubble test. Contact DOGGR to witness.
95. Weld on well identification plate.
96. Release rig and move off.
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 14 of 15
Spud Date:Conversion Date:TD ‐ MD:TD ‐ TVD:API Number:
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
MD Age Hole
990 ft 11‐3/4" 42ppf H40 STC
7.0" Speed Tite8585 ft_
GLE = 2,927 ftRKB = 6.35 ft
Packer = 8486 ft
TOC = ±7000'
1‐Oct‐19536‐June‐19738,749 ft8,733 ft03700776
Southern California Gas Co.Standard Sesnon #25
Current Status
8748 ft_
Aliso Canyon RCA Project Rev: 18 Feb 2018
7.0" Casing29 ppf N80 Surf ‐ 939’23 ppf J55 939 ‐ 2398'23 ppf N80 2398 – 6308 ft26 ppf N80 6308 – 8282 ft
29 ppf N80 8282 – 8585 ft
TD = 8,749 ft MD8,733 ft TVD
5‐1/2" TOL = 8559'
Form. Zone.
16”
10‐5/8”
6.0"5‐1/2" 20.0 ppf J55 FJ (slotted ‐ 120 mesh)
TOC A Annulus 7590'TOC Tubing 7580'
Upper Plio
cene
Lower Plio
cene
Middle M
iocene
Old Santa Susana Fault _1635
Modelo
Topanga
_4200Yng Santa Susana Fault
Pico
_8182Mio‐Plio Unconformity
Pico
Modelo
Middle M
iocene
_1912
_2703
_3412
Pico‐1
Pico‐2
Pico‐3
Pico‐4_3992
_4650Pico
Aliso
_5820
_6566
Porter
_7350
Upper Del Aliso
Mid DA _7588
Lower DA
_8395Cap Rock
Sesnon
20" Conductor
CIBP 7572’Tubing Cut 7555’
7” Casing Patch7” Tieback Casing939’ to Surface
9 ppg Flowzan Fluid to Surface
Tubing Hanger Installed
3‐1/2” Workstring9.3 ppf EUE
EOT approx. 7524’ (1 joint above the tubing stub at 7555’)
Holes in 11‐3/4” Casing144 – 300’
Perforations8510 – 8538’8542 – 8559’
SS-25 Phase 3A Contingency Part 2 Summary Steps Rev 5 March 30 2018 el v01 15 of 15
Spud Date:Conversion Date:TD ‐ MD:TD ‐ TVD:API Number:
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
MD Age Hole
990 ft
11‐3/4" 42ppf H40 STC
7.0" Speed Tite8585 ft_
GLE = 2,927 ftRKB = 6.35 ft
Packer = 8486 ft
1‐Oct‐19536‐June‐19738,749 ft8,733 ft03700776
Southern California Gas Co.Standard Sesnon #25
Proposed Abandonment
8748 ft_
Aliso Canyon RCA Project Rev: 21 Mar 2018
7.0" Casing29 ppf N80 Surf – 1040 ft23 ppf J55 1040 – 2398 ft23 ppf N80 2398 – 6308 ft26 ppf N80 6308 – 8282 ft
29 ppf N80 8282 – 8585 ft
TD = 8,749 ft MD8,733 ft TVD
5‐1/2" TOL = 8559'
Form. Zone.
16”
10‐5/8”
6.0"5‐1/2" 20.0 ppf J55 FJ (slotted ‐ 120 mesh)
TOC A Annulus 7590'TOC Tubing 7580'
Upper Plio
cene
Lower Plio
cene
Middle M
iocene
Old Santa Susana Fault _1635
Modelo
Topanga
_4200Yng Santa Susana Fault
Pico
_8182Mio‐Plio Unconformity
Pico
Modelo
Middle M
iocene
_1912
_2703
_3450
Pico‐1
Pico‐2
Pico‐3
Pico‐4_3992
_4650Pico
Aliso
_5820
_6566
Porter
_7350
Upper Del Aliso
Mid DA _7588
Lower DA
_8395Cap Rock
Sesnon
20" Conductor
CIBP 7572’Tubing Cut 7555’
580’ Cement Retainer800’ BFW860’ Cement Retainer7” Tieback Casing ±1024’ to ±980’
2703' PGS
3450’ Annulus Sqz
4650’ A1
5527’ A36
5820’ UP
6245’ LP
6566’ UDA 1
Perforations8510 – 8538’8542 – 8559’
ETOC 650’Sqz Holes 800’
ETOC 2203‘Sqz Holes 2703’
ETOC 3250‘Sqz Holes 3450’
ETOC 4504‘Sqz Holes 4654’
ETOC 5377‘Sqz Holes 5527’
ETOC 5670‘Sqz Holes 5820’
ETOC 6095‘Sqz Holes 6245’
ETOC 6416‘Sqz Holes 6566’
TOC ±7000’
Aliso Canyon Base of Fresh Water, 800’MD
Base of Fresh Water (BFW) for Aliso Canyon is noted in California Oil and Gas Fields Vol 2, a publication
by the California Division of Oil and Gas, as 100‐800’ (Attachment 1). BFW is identified as 3,000ppm
Total Dissolved Solids (TDS). It is important to note the Summary of Operations California Oil Fields 29th
Annual Report of the State Oil and Gas Supervisor states there are no subsurface waters suitable for
domestic or irrigation purposes to protect at Aliso Canyon. This established the original 500’ surface
casing depth (Attachment 2).
800’+/‐ was selected as a conservative BFW for the majority of the field1 instead of using 100’ or even no
BFW. This depth was also confirmed by DOGGR agents at the field. Petrophysical analysis of BFW at the
Aliso Canyon field is complicated by many factors. The west field where SS‐25 is located contains a
basalt layer within the Topanga formation (Figure 1) that has a strong electric log signature (Figure 2),
highlighting the abrupt transition in lithology. At SS‐25 this basalt layer is present from 845’MD to
969’MD (Figure 3). Another complicating factor for petrophysical analysis is the preference to drill with
oil‐based mud due to difficult shallow drilling conditions. The oil emulsion mud used to drill the shallow
section of SS‐25 had an Rm of about 2.0 OHMM at reservoir temperature which interferes with
petrophysical determination of BFW. SS‐25 also has only SP and Resistivity logs for petrophysical
analysis. SP method of Rw (and salinity) requires a known 100% wet, clean sand. The shallow geology
of Aliso Canyon is known to have tar staining and interbedded shales (Figure 3) from mudlogs; these
conditions will also underestimate calculated salinities.
Blade Energy Partners calculated formation water salinity of neighboring wells drilled in the early 1970s:
SS‐25A (surface casing set at 806’MD) and SS‐25B (surface casing set at 900’MD). The resulting
calculations (Figure 4) show formation salinity of 6,000ppm at approximately 900’MD (no logs were
acquired in the surface casing section) thereby indicating 800’MD BFW to be a conservative depth for
the three wells at the SS‐25 well site.
1 Note the western part of the field has Modelo/Topanga faulted out and a petrophysically established BFW at the PEupth marker.
F
Figure 1: Full field cross section showing basalt isolated to the west field.
Figure 2: SS‐25 shallow e‐log from 1953 showing strong resistivity response of Topanga basalt
Figure 3: Partial SS‐25 Stratigraphic Column
Figure 4: SS‐25A and SS‐25B Salinity calculation from SP