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Husky has implemented an environmental effects monitoring program designed with public input and the assistance of an independent group of qualified persons. The program was subject to review and approval by the Canada - Newfoundland and Labrador Offshore Petroleum Board (CNLOPB) and other environmental regulatory agencies. Baseline data was collected in the White Rose Field in 2001 and 2002, and the program was designed based on this information.
The first year of program implementation was carried out in 2004 after development drilling commenced in October of 2003.
The White Rose Production Phase Environmental Effects Monitoring Program Design document and the Baseline Data Collection Reports can be viewed or downloaded by clicking on the following:
Environmental Effects Monitoring Program Report (2005 Volume 1)
Environmental Effects Monitoring Program Report (2004 Volume 1)
Environmental Effects Monitoring Program Design Report (May 2004)
Baseline Data Collection Supplementary Report (July 2003)
Baseline Data Collection Report (July 2000 - large file)
While Husky has a policy of zero-tolerance for spills and other environmental incidents it also recognizes that these events sometimes occur. When these events occur it is important that they are fully investigated to determine root causes so the risk of re-occurrence is minimized or eliminated.
The table below summarizes the types and magnitude of unintentional spills and other incidents experienced offshore by the White Rose Project from October 2003 to October 2004, the year immediately prior to the first round of Environmental Effects Monitoring Program sampling. Any and all spills to the ocean, regardless of volume, are immediately reported to the CNLOPB and the Canadian Coast Guard Spill Reporting Centre.
Summary of environmental losses from White Rose offshore operations - October 2003 to October 2004
|
Losses Operation |
Hydrocarbons |
Drilling Fluids |
Other |
| Drilling |
One litre of hydraulic fluid lost from crane in one incident |
99.1 cubic metres of synthetic drilling fluid lost in two incidents |
- |
ROV
Operations - Drilling |
77 litres of hydraulic fluid lost during ROV (remotely operated vehicle) operations in ten incidents |
- |
- |
ROV
Operations - Construction |
32 litres of hydraulic fluid lost during ROV operations in three incidents |
- |
- |
| Well Testing |
115 litres of crude oil lost during well testing in seven incidents |
- |
- |
| Supply Vessel Operations |
20 litres of hydraulic fluid lost from thrusters in one incident |
- |
Apparent evidence of night collision with marine mammal in one incident - loss of five empty containers overboard in transit to port in one incident |
| Construction Vessel Operations |
15 litres of hydraulic fluid lost in one incident |
- |
- |
The losses in each of the above categories were fully investigated to determine root causes and identify measures to eliminate or minimize the risk of reoccurrence. For example, the loss of crude oil during an initial well test occurred despite the use of best available technology. Findings were incorporated into subsequent well testing resulting in no crude oil loss to the environment.
Under the Atlantic Accord Implementation Act the CNLOPB has developed guidelines governing the kinds and concentrations of discharges that can be released to the marine environment. The Offshore Waste Treatment Guidelines (August 2002) are available on the CNLOPB's website. Such discharges are termed authorized discharges. Discharges or emissions not addressed and managed under these guidelines are deemed unauthorized discharges or in the case of petroleum - spills.
The following describes the authorized discharges from Husky's drilling operations controlled under the Offshore Waste Treatment Guidelines.
Husky employs both water-based and synthetic fluid based drill muds in its drilling programs.
Water-based mud is used for upper drill hole sections while synthetic-based fluids are used in deeper hole sections, especially during directional drilling operations, where drilling conditions are more difficult and hole stability is critical to safety and success.
From October 2003 to October 2004 the total mass of drill cuttings and water based drilling fluids discharged to the sea floor at the three drill sites on the White Rose field was 20,285 metric tonnes. 18,610 metric tonnes were rock cuttings and 1,675 metric tonnes were water-based drilling fluids.
These water-based mud and cuttings discharges occurred at the three drill sites in the following proportions: 68 percent at the Southern Glory Hole (9 wells), 15% at the Northern Glory Hole (2 wells) and 17 percent at the Central Glory Hole (2 wells).
From October 2003 to October 2004, 5,912 metric tonnes of drill cuttings and synthetic-based drilling fluids were discharged to the sea floor at the three White Rose drill sites. 5,434 metric tonnes was rock cuttings and 478 metric tonnes was synthetic based drill fluid.
These synthetic based drilling fluid and cuttings discharges were in the following proportions: 91 percent at the Southern Glory Hole, nine percent at the Northern Glory Hole. No synthetic-based fluid drilling took place at the Central Glory Hole during this period.
To manage and minimize the discharge of synthetic-based drilling fluids to the marine environment Husky employs the best available technology and practices. These efforts include installing additional and specialized centrifuge technology on its drill rig and managing drilling fluids to enhance opportunities for reusing fluids by recovering and recycling barite and other constituents.
The CNLOPB's Offshore Waste Treatment Guidelines require operators to target a value of 6.9 percent or less synthetic based drill fluid on cuttings.
Husky has worked diligently to achieve this target under various conditions. Depending on drilling conditions for different wells and well sections Husky's performance has varied from approximately 4.5 to 9.5 percent synthetic oil on cuttings based on 48-hour rolling averages of measurements made in accordance with regulatory requirements.
The following table summarizes Husky's performance in trying to reach the CNLOPB's 6.9 percent target.
| Drilling Site |
Southern
Glory Hole |
Northern
Glory Hole |
Central
Glory hole |
| Range of % Synthetic Fluid on Discharge Cuttings for each well drilled within a glory hole |
6.73 to 10.76 |
4.41 to 13.32 |
No synthetic base fluid drilling carried out during reporting period |
| 3.84 to 12.60 |
| 6.21 to 11.51 |
| 7.75 to 10.15 |
The operational discharges from Husky's drilling platform operations other than drill cuttings and drilling mud over the past year are summarized below. Each discharge stream is briefly described following the table.
| Authorized Discharges (m3) |
2003 |
2004 |
| Oct |
Nov |
Dec |
Jan |
Feb |
Mar |
Apr |
May |
Jun |
July |
Aug |
Sept |
Oct |
| Bilge Water |
14 |
2 |
0 |
11.1 |
3 |
0 |
4.5 |
12.5 |
5.5 |
9 |
0 |
10.8 |
11 |
| Glycol-based fluid from Blow Out Preventer |
0 |
6.6 |
5.7 |
7 |
7.6 |
3.9 |
0.5 |
2.1 |
0.7 |
0.9 |
6.9 |
2.7 |
10.7 |
| Deck Drainage |
105.9 |
100.5 |
201.4 |
106.5 |
121.3 |
193 |
119 |
80 |
115 |
167.5 |
143 |
87 |
208 |
| Glycol-based fluid from Subsea Equipment |
0 |
0 |
0 |
0 |
0 |
0 |
0 |
168 |
129 |
0 |
0 |
0 |
0 |
- Bilge and deck drainage discharges are maintained at 15 parts per million (ppm) or less
- BOP (blow-out preventer) testing is to ensure functionality and therefore safety and environmental protection; volumes are the amount of active ingredient i.e., glycol and erifon at maximum of 42 and 2 percent respectively of total volume discharged
- Losses from subsea equipment during hookup and installation work during is unavoidable; volumes are the amount of active ingredient i.e., glycol and triethanolamine at a maximum of 70 percent and of 5 percent of total volume discharged
The machinery and other spaces aboard the drill rig must have oily water treatment in accordance with International Marine Organization requirements. To that end all bilge water is subject to treatment using oily water separators that are designed to conform with the oil in water discharge limit of 15 parts per million at a maximum and automatic alarms are in place should this limit be exceeded.
Regulatory requirement and responsible drilling practices require the use of a blow-out preventer located on the seabed on the drill string. This equipment is comprised of hydraulically driven rams that, in the event of an incident, can be activated to stop oil under pressure from being released up the drill string. Like all safety equipment the BOP must be tested regularly and put in place at the beginning of each well drilling operation. Testing and normal operations of the BOP result in the lost of hydraulic fluids which in this case are glycols mixed 50:50 with water. The amounts of these fluids that are discharged vary in relation to the amount of drilling activity that takes place over time.
Minimizing the loss of hydrocarbons from drilling operations requires continuous effort in terms of engineered containment and appropriate operating polices and procedures. Guidelines require that deck drainage from installations in the Newfoundland Offshore Area contain less than 15 parts per million hydrocarbons. For areas on the drilling rig where oily drainage is a risk containment measures are in place and oily water is managed to ensure that when discharged it meets guidelines. If this cannot be assured by inspection and/or testing on site then there is provision to bring it to shore for treatment and disposal. In addition, provisions and procedures are in place to recycle some deck drainage water in the drill cuttings treatment process to minimize the use of fresh seawater.
During the installation of subsea infrastructure e.g., risers, flow lines, manifolds etc. there are routine and unavoidable losses of glycol-based hydraulic fluids containing 50 percent water. The volumes of these fluids that are lost vary with the installation operations being undertaken.
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