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July 24, 2012 BSEE
BSEE and BOEM Workshop
with Government of Israel
Application for Permit to Drill
Joe Levine
BSEE
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Exploration or Development Plan reviewed by BOEM
Environmental Reviews
Identify Drilling Locations
Identify Rig type (platform, MODU)
Oil Spill Contingency Plans
Worst Case Discharge (WCD)
Application for Permit to Drill reviewed by BSEE
Ensure permit and drilling operations to be conducted complies
with regulations
July 24, 2012 BSEE
Application for Permit to Drill (APD) Overview
• BSEE Review and Written Approval Required
for
– Each Well, Sidetrack, Deepen
• Purpose
- Regulatory Compliance
- Outlines Drilling Program
• Major Areas
- Operational Characteristics of Rig
- Well Design
- Equipment Use and Testing
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Permits are submitted through BSEE ewell system
Ewell is an electronic system that operators use to submit permits to BSEE
BSEE reviews the permit and can electronically return the permit to the operator with a list of items that need to be addressed
The operator than can resubmit the permit to BSEE when they have addressed the issues
An electronic approval is sent to the operator when BSEE approved the permit
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Rig Information USCG Certificate of Inspection/Letter of Compliance
ABS/DNV Load Line Certificate
Safe Welding Area
Rated Rig Drilling Depth
Rated Rig Water Depth
Rig Maximum Environmental Conditions
Hurricane Season Ratings
Evacuation Plan for MODU (COCP for ice)
For platform rig - structural assessment of platform rig to be installed
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Oil Spill Financial Responsibility Verify operator Oil Spill Financial Responsibility on file
Verify effective and expiration dates
30 CFR 253 regulations
Up to $150 million (depends on number of facilities, facility location, WCD volume)
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Plat Information Plat drawn to scale 1” = 2000 feet
Surface and subsurface location of well
Surface and subsurface location of well shown in feet from lease line
Surface and subsurface location of previously drilled wells shown within the block of well proposed to be drilled
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Exploration or Development Plan Verify plan approval
Check conditions of approval and or mitigations that apply to APD Shallow hazards, archeological, buoy pipelines, cementing, discharges (shunting around coral reefs)……
For moored rigs, confirm anchor pattern in APD is same as what was in plan
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Geologic Information
Significant markers
Hydrocarbon bearing zones
Shallow hazards
Shallow water flows
Abnormally pressured zones
Lost circulation zones
Hydrogen Sulfide Presence H2S Plan
Plans for mitigating hazards
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Drilling Prognosis Drilling procedure by hole section
Cementing programs (certified by professional engineer) Type, density, volume, top
Drilling fluids program Type, density, volume, mud onsite
Logging program Type, interval
Well testing program (if any)
– Prior Notification
– Fluid Disposal
– MMS Witness
– Data Collection
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Engineering Calculations Casing design (certified by professional engineer)
Casing test pressures
Verify that dual mechanical barriers are installed in production casing (in addition to cement) (certified by professional engineer)
Cement volumes (certified by professional engineer)
Maximum anticipated surface pressure (MASP) calculations and assumptions
July 24, 2012 BSEE
Maximum Anticipated Surface Pressure (MASP)
• Formulas and Assumptions Vary From Company to Company
• Sample BSEE Calculations
– MASP Surface Shoe = FG – GG
– MASP Intermediate Shoe = BHP – Hydrostatic Pressure (70% Gas and 30 % Mud Column)
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Well Control Well control procedure while
drilling
tripping
Well control procedure for annular preventer
July 24, 2012 BSEE
Diverter System
• Purpose
– Means of Directing Shallow Flows Away From Rig
– Provides Time to Abandon Facility if Needed
• As Part of APD Operator Must Submit a Variety of
equipment and operational type information
• Needs to be Installed When Drilling Conductor or
Surface Hole
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Plan view
Elevation view
Diverter spool outlet size
Line length
Diameter (10 or 12 inch)
Burst rating
Radius of curvature
Targeted 90’s
Valve type
Valve Size
Valve location
Operating procedure
Test pressure
DIVERTER
July 24, 2012 BSEE
July 24, 2012 BSEE
Diverter Testing
• Actuate When Installed
• Actuate Every 24 Hours While in Use
• Pressure Test to 200 psi Every 7 Days
• Alternate Tests Between Control Stations
July 24, 2012 BSEE
Application for Permit to Drill (APD)
One annular preventer
Two pipe rams
One blind/shear ram
Kill line with two full opening valves
Fill-up line above the uppermost
preventer
Rated working pressure of the choke manifold and components equal to or greater than working pressure of the ram BOP’s
Accumulator system provides 1.5 times the volume of fluid capacity required to close and hold all BOP components
BOP control drawings
Surface BOP
July 24, 2012 BSEE
Application for Permit to Drill (APD)
One annular preventer
Two pipe rams
One blind/shear ram
Kill line with two full opening valves
Fill-up line above the uppermost
preventer
Dual pod system for independent operation
of BOP
Secondary BOP control system with ROV
intervention capabilities
Deadman and autoshear system
3rd party verification of BOP
BOP control drawings
Verify ROV can close, at a minimum, one set of pipe rams, one set of blind/shear rams and
disconnect from LMRP
Subsea BOP System
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Rated working pressure of the choke
manifold and components equal to
or greater than working pressure of
the ram BOP’s
Accumulator system
BOP to meet or exceed API RP 53,
Section 13.3
BOP control drawings
Procedures for all ROV hot stabs
Procedure for testing deadman
system
Confirm at least one ROV hot stab will be tested on the seafloor
Review stump test procedure
Subsea BOP System Cont.
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Blind/Shear Ram Information
Manufacturer
Type
Max. pipe size that can be sheared
Shearing pressure
3rd party verification that shear rams
can shear strongest pipe to be used
in the well at maximum anticipated
wellhead pressure
Other
BOP Sizes
BOP working pressure
BOP test pressures
Subea BOP System Cont.
July 24, 2012 BSEE
Blowout Preventer Pressure Testing
• Frequency
−When Installed
−Within 14 Days of Previous Test
−Before Drilling Out Each String or Liner
• Test Pressures
−Low Pressure Between 200 - 300 psi
−High Pressure to Rated Working Pressure
(RWP)
−Annular to 70% of its’ Minimum Internal Yield
Pressure (MIYP)
July 24, 2012 BSEE
Blowout Preventer Pressure Testing
• High pressure can be to less then RWP depending on
MASP calculations
• Each test - hold pressure for 5 minutes. If a component
does not test, remedy and retest
• Stump test subsea BOP before installation on seafloor
with water (BSEE witnesses all)
• Alternate tests between control pods and control stations
for subsea stacks
• Function tests annular/rams every 7 days between
pressure tests
• Visual inspection - once each day including riser. Use
TV camera for subsea equip.
July 24, 2012 BSEE
Blowout Preventer Test Records
• Record all Test Pressures on Pressure
Chart
• Chart Certification by Onsite Company
Representative
• Identify any Problems Encountered During
Test and how Remedied
• Retain all Records for 2 Years at Facility
or Onshore Location
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Casing Design
Casing size and type
Burst rating
Collapse rating
Safety factors for tension,
collapse, and burst
Test pressures
Design calculations
Setting depth
Connection type
July 24, 2012 BSEE
Casing Pressure Testing
• Positive Pressure Test
‒ Imposes a force on inside of casing that
meets or exceeds formation pressure to
check for leak path from casing to annulus
– Required on conductor casing (200 psi) and
on surface, intermediate, production casings
(70% MIYP)
– Need to have 30 minute test with less than a
10% pressure decline
July 24, 2012 BSEE
Casing Pressure Testing
• Negative Pressure Test
– Reducing pressure from inside of casing to
check for leak path from annulus to casing
– Perform on intermediate and production
casing strings
– Operator proposes methodology to BSEE
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Cementing Information Type(s) of cement to be used for each casing string
Volume of cement for each casing string
Wait on cement (WOC) time
Statement that they will use best practices in API RP 65 (shallow water flow), and/or Part 2 (deepwater)
Procedures for verifying top of cement
Procedures for remedial cementing
Annular washout for abandonment purposes
July 24, 2012 BSEE
Cementing
• Purpose – Bonds Casing to Hole
– Prevents Fluids in One Formation from Migrating to Other Formations
• Types – Variety of Oilfield Cements Based on Desired Properties
– Liquid, Foam, HPHT, Class G, Class H
• Additives – Modify Cement Properties
– Accelerators, Retarders, Weight Materials, Nitrogen, Freeze Protection (Salt)
• Pumping Equipment – High Pressure Equipment Moves Cement Down hole
July 24, 2012 BSEE
BSEE Cementing Requirements
• Structural Casing – Normally Driven, Cement Back to Mud Line (ML)
• Conductor Casing – Cement Back to ML
• Surface Casing – Cement at Least 200’ (61 Meters) Above Conductor Casing Shoe
• Intermediate Casing – Cover and Isolate Hydrocarbon and Abnormal Pressure Zones (at least 500’ above casing shoe or pressured zone)
• Production Casing – Isolate Hydrocarbon Zones (at least 500’ above casing shoe or pressured zone)
• Liner – Cement Lap Above Casing Shoe
• Wait on Cement (WOC) – cement must remain under pressure for 12 hours (surface, intermediate, and production casing) or 8 hours (conductor casing) before drilling resumes
July 24, 2012 BSEE
Application for Permit to Drill (APD)
Other Mud weight, pore pressure, fracture pressure plot
Anticipated safe drilling margin
Hydrogen sulfide contingency plan (if applicable)
Proposed well schematic
Coring program
Directional program
Departure request/alternative compliance request
Formation integrity test
Mud program
Containment
July 24, 2012 BSEE
32
MUD WEIGHT, PORE PRESSURE, FACTURE MUD WEIGHT, PORE PRESSURE, FACTURE
GRADIENT, AND CASING PLOTGRADIENT, AND CASING PLOT
0
500
1000
1500
2000
2500
3000
3500
4000
8 9 10 11 12 13 14 15
MUD WEIGHT (PPG)
TR
UE
VE
RT
ICA
L D
EP
TH
(F
EE
T)
PORE PRESSURE PLANNED MUD WEIGHT FACTURE GRADIENT
7-5/8”
10-3/4”
16”
24”
July 24, 2012 BSEE
DRILLING FLUIDS
• Volume and Type of
Fluid
• Additives
• Minimal Quantities On
Location
• Time to Re - Supply
(Barite)
July 24, 2012 BSEE
APD Form
July 24, 2012 BSEE
APD Form
July 24, 2012 BSEE
HYDROGEN SULFIDE
• Significant Percentage of OCS Production Contains H2S
• Requirements Apply to
– Drilling
– Completions
– Workovers
– Production
• BSEE H2S Requirements are Based on Likelihood of Encountering Gas
July 24, 2012 BSEE
H2S PERMITTING
• Area Classification – Absent
– Present
– Unknown
• Plan of Exploration or Development and Production Plan to Include Classification
• H2S Contingency Plan Required for Areas Classed as: – Present
– Unknown
July 24, 2012 BSEE
H2S CONTINGENCY PLAN REQUIREMENTS
• Key Elements Include
– Person in Charge
– Personnel Duties
– Agency Notification
– Actions to Take for 20 ppm
– Briefing (Muster) Areas
– Evacuation Criteria
July 24, 2012 BSEE
H2S CONTINGENCY PLAN REQUIREMENTS
• Key Elements Include
– Protective Breathing Equipment
– Precautions for Helicopters and Vessels
– H2S Detector Locations
– H2S Flaring Procedures
– Sulphur Dioxide Precautions
– Training and Drills
